Securities Registration Statement (s-1)

Table of Contents

As filed with the Securities and Exchange Commission on September 12, 2014

 

Registration No. 333-            

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

Form S-1

REGISTRATION STATEMENT

UNDER

THE SECURITIES ACT OF 1933

 

Energy & Exploration Partners, Inc.

(Exact name of registrant as specified in its charter)

 

Delaware   1311   80-0839466

(State or other jurisdiction of

incorporation or organization)

 

(Primary Standard Industrial

Classification Code Number)

 

(I.R.S. Employer

Identification No.)

 

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, Texas 76102

(817) 789-6712

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

 

Tom D. McNutt

Executive Vice President, General Counsel and Secretary

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, Texas 76102

(817) 789-6712

(Name, address, including zip code, and telephone number, including area code, of agent for service)

 

Copies to:

 

Charles H. Still, Jr.

Bracewell & Giuliani LLP

711 Louisiana Street, Suite 2300

Houston, Texas 77002

(713) 221-3309

 

Kirk Tucker

Mayer Brown LLP

700 Louisiana, Suite 3400

Houston, Texas 77002

(713) 238-3000

 

Approximate date of commencement of proposed sale to the public: As soon as practicable after the effective date of this registration statement.

 

If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, check the following box:  ¨

 

If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  ¨

 

If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  ¨

 

If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  ¨

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

 

Large accelerated filer  ¨   Accelerated filer  ¨  

Non-accelerated filer  x

(Do not check if a

smaller reporting company)

  Smaller reporting company  ¨

 

CALCULATION OF REGISTRATION FEE

 

Title of Each Class of

Securities to Be Registered

  

Proposed Maximum

Aggregate

Offering Price(1)(2)

 

Amount of

Registration

Fee

Common Stock, par value $0.01 per share

   $400,000,000   $51,520(3)

 

 

(1)   Estimated solely for the purpose of calculating the registration fee pursuant to Rule 457(o) under the Securities Act of 1933, as amended.
(2)   Includes shares of common stock issuable upon exercise of the underwriters’ option to purchase additional shares of common stock.
(3)   Pursuant to Rule 457(p) under the Securities Act of 1933, as amended, $33,573.53 of the fee is being offset by the fee previously paid in connection with the registration statement on Form S-1 initially filed by the registrant on September 10, 2012 (File No. 333-183808).

 

The registrant hereby amends this registration statement on such date or dates as may be necessary to delay its effective date until the registrant shall file a further amendment which specifically states that this registration statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933 or until the registration statement shall become effective on such date as the Commission acting pursuant to said Section 8(a), may determine.

 

 

 


Table of Contents

The information in this prospectus is not complete and may be changed. We and the selling stockholders may not sell these securities until the registration statement filed with the Securities and Exchange Commission is effective. This prospectus is not an offer to sell these securities and it is not soliciting an offer to buy these securities in any state where the offer or sale is not permitted.

 

SUBJECT TO COMPLETION, DATED SEPTEMBER 12, 2014

 

PROSPECTUS

 

             Shares

 

LOGO

 

Energy & Exploration Partners, Inc.

Common Stock

$         Per Share

 

 

 

We are offering              shares of our common stock, and the selling stockholders are offering              shares of our common stock. We will not receive any proceeds from the sale of our common stock by the selling stockholders. This is the initial public offering of our common stock. Prior to this offering, there has been no public market for our common stock. The initial public offering price of our common stock is expected to be between $         and $         per share. We have applied to list our common stock on the New York Stock Exchange under the symbol “ENXP.”

 

We are an “emerging growth company” under the federal securities laws and will be subject to reduced public company reporting requirements. See “Summary—Implications of Being an Emerging Growth Company.”

 

 

 

Investing in our common stock involves risks. Please see the section entitled “Risk Factors” starting on page 15 of this prospectus to read about risks you should consider carefully before buying shares of our common stock.

 

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or passed upon the accuracy or adequacy of this prospectus. Any representation to the contrary is a criminal offense.

 

 

 

     Per Share      Total  

Public offering price

   $                $            

Underwriting discount(1)

   $                $            

Proceeds, before expenses, to us

   $                $            

Proceeds to selling stockholders(2)

   $                $            

 

(1)   For additional information about underwriting compensation, please see “Underwriting.”
(2)   Expenses associated with the offering of shares by the selling stockholders, other than underwriting discounts, will be paid by us.

 

We have granted the underwriters a 30-day option to purchase up to an additional              shares of our common stock at the public offering price, less the underwriting discount, to cover any over-allotments.

 

The underwriters expect to deliver the shares of common stock on or about                      , 2014.

 

 

 

Citigroup     Credit Suisse  

RBC Capital Markets

 

 

 

The date of this prospectus is                      , 2014.


Table of Contents

TABLE OF CONTENTS

 

PROSPECTUS SUMMARY

     1   

RISK FACTORS

     15   

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

     39   

USE OF PROCEEDS

     41   

DIVIDEND POLICY

     42   

CAPITALIZATION

     43   

DILUTION

     44   

SELECTED CONSOLIDATED FINANCIAL DATA

     45   

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     46   

BUSINESS

     70   

MANAGEMENT

     95   

EXECUTIVE COMPENSATION

     100   

CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS

     106   

PRINCIPAL AND SELLING STOCKHOLDERS

     110   

DESCRIPTION OF CAPITAL STOCK

     112   

SHARES ELIGIBLE FOR FUTURE SALE

     117   

MATERIAL U.S. FEDERAL INCOME TAX CONSIDERATIONS FOR NON-U.S. HOLDERS

     119   

UNDERWRITING

     122   

LEGAL MATTERS

     129   

EXPERTS

     129   

WHERE YOU CAN FIND MORE INFORMATION

     129   

INDEX TO FINANCIAL STATEMENTS

     F-1   

GLOSSARY OF SELECTED OIL AND NATURAL GAS TERMS

     A-1   

 

 

 

You should rely only on the information contained in this document and any free writing prospectus we provide you. We, the selling stockholders and the underwriters have not authorized anyone to provide you with additional or different information. We, the selling stockholders and the underwriters are offering to sell, and seeking offers to buy, these securities only in jurisdictions where offers and sales are permitted. The information in this prospectus is accurate only as of the date of this prospectus, regardless of the time of delivery of this prospectus or any sale of these securities.

 

Through and including                     , 2014 (the 25th day after the date of this prospectus), all dealers effecting transactions in these securities, whether or not participating in this offering, may be required to deliver a prospectus. This is in addition to a dealer’s obligation to deliver a prospectus when acting as an underwriter and with respect to an unsold allotment or subscription.

 

Industry and Market Data

 

The market data and certain other statistical information used throughout this prospectus are based on independent industry publications, government publications or other published independent sources. Some data is also based on our good faith estimates. Although we believe these third-party sources are reliable and that the information is accurate and complete, neither we nor the selling stockholders, nor the underwriters have independently verified the third-party information and our estimates may differ materially from actual data. The industry in which we operate is subject to a high degree of uncertainty and risk due to a variety of factors, including those described in the section titled “Risk Factors.” These and other factors could cause results to differ materially from those expressed in these publications.

 

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PROSPECTUS SUMMARY

 

This summary provides a brief overview of information contained elsewhere in this prospectus. Because it is abbreviated, this summary does not contain all the information that you should consider before investing in our common stock. You should read the entire prospectus carefully before making an investment decision, including the information presented under the headings “Risk Factors,” “Cautionary Note Regarding Forward-Looking Statements” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the historical and pro forma financial statements and the notes thereto included elsewhere in this prospectus. Unless the context otherwise requires, references in this prospectus to “we,” “us,” “our” or “our company” refer to Energy & Exploration Partners, Inc. and its subsidiaries. Unless otherwise indicated, information presented in this prospectus assumes that the underwriters’ option to purchase additional shares of our common stock is not exercised. We have provided definitions for some of the industry terms used in this prospectus in the “Glossary of Selected Oil and Natural Gas Terms.”

 

Overview

 

We are an independent exploration and production company focused on the acquisition, exploration, development and exploitation of conventional and unconventional oil and natural gas resources. As of July 31, 2014 we owned approximately 92,828 net acres in three basins: the East Texas Basin where we are pursuing opportunities in the Lower Cretaceous formations of the Buda, Georgetown, Edwards and Glen Rose (the Buda-Rose play), the Woodbine sandstone and the Eagle Ford shale, which we refer to collectively as the East Texas stacked play; the Permian Basin in West Texas; and the Denver-Julesburg Basin in Wyoming, which we refer to as the DJ Basin. We target liquids-rich resource plays and have built our leasehold acreage position through direct acquisitions from mineral owners and other exploration and production companies. Our management team has extensive engineering, geological, geophysical and technical expertise in our operating areas.

 

Giving pro forma effect to the Ft. Trinidad acquisition described below, as of June 1, 2014, we had total estimated proved reserves of 41,903 MBoe, 11,405 MBoe of which were developed and 30,499 MBoe of which were undeveloped. See “—Summary Reserve Data.” Pro forma for the Ft. Trinidad acquisition, our average daily net production was approximately 6,016 Boe/day for the three months ended March 31, 2014, approximately 8,363 Boe/day for the three months ended June 30, 2014 and approximately 10,601 Boe/day for the two months ended August 31, 2014.

 

Our primary area of focus is the East Texas stacked play, in which we owned approximately 71,577 net acres as of July 31, 2014. On July 22, 2014, we completed the purchase of approximately 18,300 net acres in the Ft. Trinidad field in the East Texas stacked play from TreadStone Energy Partners, LLC, or TreadStone, including interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells waiting on completion, a 3-well salt water disposal system and approximately 30 square miles of 3D seismic, for a purchase price of approximately $693 million in cash, after initial post-closing adjustments. We refer to this transaction as the Ft. Trinidad acquisition. During the period from July 22, 2014 to August 31, 2014, five gross (five net) wells commenced drilling on the Ft. Trinidad acreage. As of August 31, 2014, 13 gross (13 net) wells were waiting on completion on the Ft. Trinidad acreage.

 

We are the operator on approximately 81% of our net acres in the East Texas stacked play. We began drilling on our operated East Texas stacked play acreage in May 2013, and we have drilled or were in the process of drilling 18 gross (18 net) operated wells on this acreage as of June 30, 2014. In addition to our acreage in the East Texas stacked play, as of July 31, 2014 we had approximately 7,089 net acres in the Permian Basin, where we have 100% operated working interests, and 14,162 net acres in the DJ Basin, where we have 100% operated working interests.

 

 

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The majority of our capital expenditure budget for 2014 through 2016 is focused on the development of our operated acreage in the East Texas stacked play. The following table presents summary data for our acreage in the East Texas stacked play and our other operating areas as of July 31, 2014 and our drilling capital budget of $160 million for the year ending December 31, 2014, $244 million for the year ending December 31, 2015 and $372 million for the year ending December 31, 2016. We also have budgeted estimated capital expenditures of $36 million for the year ending December 31, 2014 and $48 million for each of the years ending December 31, 2015 and 2016 for land acquisition, leasehold extension, seismic surveys and other capital needs. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources” and “Business—Capital Budget.”

 

    Drilling Capital Budget(1)  
          January 2014 -
December 2014
    January 2015 -
December 2015
    January 2016 -
December 2016
 
    Net Acres     Net Wells     $     Net Wells     $     Net Wells     $  
                (in millions)           (in millions)           (in millions)  

East Texas Stacked Play(2)

             

Horizontal Woodbine

    71,577        6      $ 40        8      $ 52        18      $ 113   

Vertical Buda-Rose

    71,577        38      $ 120        69      $ 192        86      $ 259   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total East Texas Stacked Play

    71,577        44      $ 160        77      $ 244        104      $ 372   

Other(3)

    21,251        —        $ —          —        $ —          —        $ —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total

    92,828        44      $ 160        77      $ 244        104      $ 372   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)   Includes approximately $49 million of drilling and completion capital spent prior to July 1, 2014.
(2)   Operated working interests range from approximately 71% to 100% and non-operated working interests range from approximately 5% to 52%.
(3)   We have 100% operated working interests in the Permian Basin and DJ Basin.

 

Our Operating Areas

 

East Texas Stacked Play

 

As of July 31, 2014, we owned approximately 71,577 net acres in the East Texas stacked play located in Madison, Grimes, Leon, Houston and Walker Counties, Texas. We believe our East Texas stacked play acreage to be prospective for up to 14 zones, including our primary near-term objectives in the Buda-Rose limestone formations of the Buda, Georgetown, Edwards and Glen Rose, the Woodbine sandstone and the Eagle Ford shale. We are currently evaluating the Austin Chalk and Sub Clarksville formations, which may eventually present us with additional drilling locations. We are also utilizing 3D seismic data to evaluate deep gas opportunities in the James Lime, Cotton Valley, Bossier and Haynesville formations.

 

The majority of our leases in the East Texas stacked play not held by production are in the second or third year of their three-year primary term and generally provide for either two- or three-year extension options. In 2014, we plan to drill 44 net wells and have budgeted $160 million for estimated drilling and completion capital expenditures on our acreage in the East Texas stacked play, of which 8 net wells were drilled and $49 million of capital expenditures were made in the first half of 2014. In 2015, we plan to drill 77 net wells and have budgeted $244 million for estimated drilling and completion capital expenditures, and in 2016, we plan to drill 104 net wells and have budgeted $372 million for estimated drilling and completion capital expenditures on our acreage in the East Texas stacked play. We anticipate that our drilling plan for 2014 and 2015 combined with acreage already held by production will result in approximately 49,000 of our net acres in the East Texas stacked play being held by production. Substantially all of the acreage acquired in the Ft. Trinidad acquisition is currently held by production.

 

 

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We began drilling on our operated East Texas stacked play acreage in May 2013, and as of June 30, 2014 we have drilled or were in the process of drilling 18 gross (18 net) operated wells on this acreage. 16 gross (16 net) operated wells have been completed and placed in production, while the other two wells were in various stages of drilling or completion. In the Ft. Trinidad acquisition, we acquired interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells awaiting completion as of July 22, 2014. During the period from July 22, 2014 to August 31, 2014, five gross (five net) wells commenced drilling on the Ft. Trinidad acreage. As of August 31, 2014, 13 gross (13 net) wells were waiting on completion on the Ft. Trinidad acreage. We expect to drill or commence drilling a total of 44 net wells during 2014, including 8 net wells drilled or completed in the first half of 2014.

 

In September 2012, we, together with other operators, contracted with a leading geophysical services company to acquire a 330-square-mile 3D seismic survey covering a majority of our operated and non-operated acreage position in Grimes and Madison Counties and the southern portion of Leon County. Seismic field acquisition activities were completed in October 2013 and interpretation is ongoing. Including the approximately 30-square-mile 3D seismic from the Ft. Trinidad acquisition, we have approximately 360 square miles of 3D seismic data covering our acreage.

 

Recently, there has been significant industry activity in the East Texas stacked play, which, for purposes of industry comparisons, we define as Brazos, Burleson, Grimes, Houston, Leon, Madison, Robertson and Walker Counties, Texas. The most active operators offsetting our acreage position include EOG Resources, Inc., Halcón Resources Corporation, Anadarko Petroleum Corporation, Cabot Oil & Gas Corporation, Devon Energy Corporation, Apache Corporation, MD America Holdings, LLC, Burk Royalty Company, Silver Oak Energy, LLC, ZaZa Energy Corporation, Contango Oil & Gas Company, Crimson Energy Partners III, L.L.C. and SM Energy Company. According to Drilling Info, Inc. there were 396 drilling permits filed in 2012 and 511 drilling permits filed in 2013 in the East Texas stacked play. According to estimates prepared by Baker Hughes Incorporated, there were 43 rigs operating in the East Texas stacked play as of August 29, 2014.

 

Other Operating Areas

 

Permian Basin

 

As of July 31, 2014, we owned approximately 7,089 net undeveloped acres in the Permian Basin with a 100% operated working interest. Our Permian Basin acreage consists of mostly contiguous acreage in Lynn County, Texas. Initial targets include the interbedded sands in the Upper and Lower Spraberry and the organically-rich carbonates and shales of the Wolfcamp, Dean and Cline intervals. Additional potential targets on our Permian Basin acreage include the Clear Fork, Canyon, Strawn and Mississippian intervals. The majority of our leases in the Permian Basin are in the third year of their three-year primary term and generally provide for two-year extension options. Our drilling capital budget does not include any amounts allocated to develop our Permian Basin acreage in 2014 and 2015.

 

DJ Basin

 

As of July 31, 2014, we owned approximately 14,162 net undeveloped acres in the DJ Basin with a 100% operated working interest. Our DJ Basin acreage is in Laramie and Goshen Counties, Wyoming. Our DJ Basin leasehold acreage is focused on the western, northern and eastern extensions of the Silo Field in Laramie County, Wyoming, and the deepest parts of the basin in Goshen County, Wyoming. We are evaluating several zones within the Niobrara shale, Fort Hays limestone and Codell sand formations. Additional targets include the J Sandstone, Dakota sandstone, Greenhorn limestone and Lyons sandstone formations along with Permian and Pennsylvanian objectives. We believe our DJ Basin leasehold acreage is in areas with a higher incidence of naturally induced faulting and fracturing and moderate to high Niobrara resistivities. The majority of our leases in the DJ Basin are in the third year of their five-year primary term and generally provide for three- to five-year extension options. Our drilling capital budget does not include any amounts allocated to develop our DJ Basin acreage in 2014 and 2015.

 

 

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Our Strategy

 

We intend to actively drill and develop our acreage position in the East Texas stacked play in an effort to maximize its value and resource potential. Through the conversion of our undeveloped acreage, which we believe has significant oil-weighted resource potential, we will seek to increase our production, reserves and cash flow while generating attractive returns on invested capital.

 

Strategically drill and develop our existing acreage positions.    We plan to strategically drill and develop our East Texas stacked play acreage. In 2013, we drilled or commenced drilling 14 net wells in the East Texas stacked play and began production from 10 net wells. For 2014, we plan to drill 44 net wells and have budgeted $160 million for estimated drilling capital expenditures in our acreage in the East Texas stacked play, including wells drilled and capital expenditures made in the first half of 2014. In 2015, we plan to drill 77 net wells and have budgeted $244 million for estimated drilling capital expenditures on our acreage in the East Texas stacked play. We believe our drilling program will allow us to develop the majority of our undeveloped acreage and to hold a significant portion of our acreage by production.

 

Leverage technology to maximize inventory of high quality drilling prospects.    The majority of our East Texas stacked play acreage is characterized by multiple productive intervals including the Buda-Rose limestone formations of the Buda, Georgetown, Edwards and Glen Rose, the Woodbine sandstone and the Eagle Ford shale. We received data from a 330-square-mile seismic survey from a leading geophysical services company starting in October 2013, and interpretation is ongoing. We also acquired approximately 30 square miles of 3D seismic data in the Ft. Trinidad acquisition. We intend to use this 3D seismic data, micro-seismic data and other advanced technologies for well planning and reservoir characterization, as well as to delineate hazards and locate bypassed pay. Our highly skilled staff of geophysicists and geologists have analyzed over 4,500 well logs in the East Texas stacked play and have extensive experience in using such technologies to optimize completions and resource recovery.

 

Enhance returns through operational efficiencies as our rig count and well count grow.    We intend to focus on the continuous improvement of our operating measures as we seek to convert our undeveloped East Texas stacked play acreage into a cost-efficient development project. We are the operator of approximately 81% of our East Texas stacked play acreage, and our acreage position is generally in large contiguous blocks. This operational control will allow us to more efficiently manage the pace of development activities and the gathering and marketing of our production and control operating costs and technical applications, including horizontal and vertical development. Our operations team will continue to evaluate our operating results against those of other operators in the area in order to benchmark our performance relative to other operators and adopt best practices to decrease drilling times, optimize completions and increase EURs.

 

Selectively acquire additional leasehold acreage in our existing core area.    We have a proven history of acquiring leasehold positions that we believe have substantial oil-weighted resource potential and can meet our targeted returns on invested capital. We plan to continue to leverage the relationships of our experienced land professionals to pursue select additional leasehold acquisitions in the East Texas stacked play that meet our strategic and financial targets.

 

Maintain sufficient liquidity to execute our capital plan.    As of June 30, 2014, giving pro forma effect to the Pro Forma Transactions described under “—Summary Historical and Pro Forma Consolidated Financial Statements,” we had approximately $132 million of cash on hand. As of September 9, 2014, we had approximately $102 million of cash on hand. We expect that net proceeds from this offering, cash on hand and cash flows from operations will fully fund our capital expenditure budget for the remainder of 2014 and for 2015. In addition, subject to obtaining the participation of existing or new lenders and other conditions, we may incur additional loans of up to $175 million under our senior secured term loan described under “—Recent Financing—Senior Secured Term Loan.” We also may pursue dispositions of non-core assets to provide additional drilling capital and liquidity. We intend to actively manage our exposure to commodity price risk through commodity derivative positions on our anticipated future production.

 

 

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Our Strengths

 

We believe we are well positioned to successfully execute our business strategies and achieve our business objectives because of the following competitive strengths:

 

Operating control over the majority of our asset portfolio.    In order to better maintain control over our portfolio, we have established a leasehold position comprised primarily of operated properties. This includes operating approximately 81% of our East Texas stacked play acreage and 100% of our Permian Basin and DJ Basin acreage positions as of July 31, 2014. As operator, we have primary control over prospect selection and exploration and development timing and capital allocation, as well as the ability to implement logistical practices that we believe will allow us to shorten the time between our drilling and completion operations and first production.

 

Large acreage position in our East Texas stacked play area.    We owned approximately 71,577 net acres in the East Texas stacked play as of July 31, 2014. The majority of our leasehold acreage is in or near areas of considerable activity by large independent operators, although such activity may not be indicative of our future operations. We believe that lease terms on our acreage and our current drilling plan allow us enough time to drill wells that will hold a substantial portion of our acreage by production.

 

Substantial drilling inventory.    We estimate there could be up to 981 net potential drilling locations across our acreage in the East Texas stacked play, including 116 vertical Buda-Rose and 25 horizontal Woodbine proved undeveloped locations, 600 vertical Buda-Rose locations based on 40-acre spacing in our core areas and 240 other potential vertical and horizontal locations. During the period from January 1, 2014 through the end of 2015, we anticipate drilling 121 net wells on our East Texas stacked play acreage, leaving us a substantial drilling inventory for future years.

 

Proximity to significant industry infrastructure and access to multiple product markets.    Our acreage in the East Texas stacked play is near substantial existing hydrocarbon gathering, transportation, processing and refining capacity, and has access to multiple product sales points. We believe our East Texas stacked play oil production can generally be sold at a price that is approximately in line with New York Mercantile Exchange-West Texas Intermediate (NYMEX-WTI) benchmark prices due to the East Texas stacked play’s proximity to the Gulf Coast. Consequently, our oil production benefits from higher pricing differentials relative to many North American crude oil producers in other areas, which can often trade at a significant discount to NYMEX-WTI benchmark prices. For example, for the six months ended June 30, 2014, the average realized price for our oil production was $99.15/Bbl compared to an average NYMEX-WTI index price of $100.81/Bbl for the same period.

 

Experienced and incentivized technical, operational and management teams.    Our senior technical team is comprised of geoscience, engineering and operational professionals who average 34 years of industry experience. Members of our technical team have previously held technical and management positions with major and independent oil and natural gas companies, including Anadarko Petroleum Corporation, Mobil Corporation, Exxon Corporation and Encana Corporation. Our core management and operational team has built our existing significant acreage positions in the East Texas stacked play and our other operating areas. Our management has been and will continue to be compensated with equity incentives, as we believe that equity ownership is one of the best ways to motivate management and employees.

 

Recent Financing

 

On July 22, 2014, in connection with the closing of the Ft. Trinidad acquisition, we completed a financing consisting of a $775 million senior secured term loan, which we refer to as the senior secured term loan, and the

 

 

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issuance of $375 million of our 8.0% convertible subordinated notes due 2019, which we refer to as the convertible notes, as described more fully below. We used a portion of the net proceeds from the financing to pay the purchase price for the Ft. Trinidad acquisition and to refinance and replace our previously outstanding senior unsecured notes, including a prepayment premium. We expect to use the remaining net proceeds to fund a portion of our 2014 and 2015 capital expenditure budget for drilling and developing our leasehold acreage, acquire additional oil and gas leases, extend expiration of our current leasehold acreage and acquire 3D seismic data.

 

Senior Secured Term Loan

 

On July 22, 2014, our wholly owned subsidiary, Energy & Exploration Partners, LLC, which we refer to as ENXP LLC, entered into the $775 million senior secured term loan with a group of institutional lenders. We have guaranteed ENXP LLC’s obligations under the senior secured term loan, which are secured by a pledge of our equity interests in ENXP LLC and substantially all of ENXP LLC’s and its subsidiaries’ assets. For a description of the senior secured term loan, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Debt Facilities and Notes—Senior Secured Term Loan.”

 

Convertible Notes Offering

 

On July 22, 2014, we issued $375 million of our convertible notes in a private placement transaction. Holders of the convertible notes may elect to convert their notes into shares of our common stock at a specified conversion price in connection with the closing of a qualified public offering. A qualified public offering is defined as the first public offering of our common stock in which the aggregate gross proceeds to us and any selling stockholders equals or exceeds $400 million and following which our common stock is listed on a U.S. national securities exchange. We expect this offering will constitute a qualified public offering.

 

Holders of the convertible notes may elect to convert their convertible notes during the period commencing on September 15, 2014 and ending on October 28, 2014. Following the completion of a qualified public offering, we may redeem, and intend to redeem, any convertible notes not converted at a price equal to 100% of the principal amount of the convertible notes redeemed, plus accrued interest. Accordingly, we expect that all of the convertible notes will be converted in connection with this offering. Assuming the conversion of all of the convertible notes and an initial public offering price of $         per share of our common stock in this offering (the midpoint of the price range set forth on the cover page of this prospectus), the convertible notes will convert into              shares of our common stock upon completion of this offering. A $1.00 increase in the initial public offering price per share would decrease the number of shares issuable upon conversion of the convertible notes by              shares, and a $1.00 decrease in the initial public offering price per share would increase the number of shares issuable upon conversion of the convertible notes by              shares.

 

Additionally, holders of the convertible notes have certain registration rights with respect to the shares of common stock issuable upon conversion of the convertible notes, including piggyback registration rights that permit holders to sell up to an aggregate 36% of those shares of common stock in a qualified public offering. We expect that some or all of the convertible note holders will exercise their rights to sell shares in this offering. See “Principal and Selling Stockholders.” For a description of the convertible notes, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Debt Facilities and Notes—Convertible Notes.”

 

 

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Corporate History; Corporate Information

 

Our company was formed as Energy & Exploration Partners, LLC in 2006 and began operations in 2008. In late 2009, we began leasing in the Eagle Ford Shale trend, primarily in McMullen and LaSalle Counties, Texas, where we leased and ultimately sold over 125,000 acres to major and independent oil and natural gas companies, including Murphy Oil Corporation and Comstock Resources, Inc. In early 2011, we began accumulating leasehold acreage in our current operating areas.

 

Energy & Exploration Partners, Inc. was incorporated on July 31, 2012 pursuant to the laws of the State of Delaware to become a holding company for our business. In August 2012, we completed a series of reorganization transactions, which we refer to collectively as our corporate reorganization. For more information on our corporate reorganization, see “Certain Relationships and Related Party Transactions—Corporate Reorganization.”

 

Our principal executive offices are located at Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, Texas 76102, and our telephone number at that address is (817) 789-6712. Our website address is http://www.enxp.com. Information contained on our website is not incorporated by reference into this prospectus, and you should not consider the information contained on our website to be part of this prospectus.

 

Risk Factors

 

An investment in our common stock involves significant risks. In particular, the following considerations may offset our competitive strengths or have a negative effect on our business, financial condition or results of operations, which could cause a decrease in the price of our common stock and result in a loss of all or a portion of your investment:

 

   

Oil and natural gas prices are volatile. A substantial or extended decline in oil and natural gas prices may adversely affect our business, financial condition or results of operations and our ability to meet our capital expenditure plans and financial commitments.

 

   

Drilling for and producing oil and natural gas are high risk activities with many uncertainties that could adversely affect our business, financial condition or results of operations.

 

   

Our exploration and development projects require substantial capital expenditures. We may be unable to obtain required capital or financing on satisfactory terms.

 

   

Drilling locations that we decide to drill may not yield oil or natural gas in commercial quantities, or at all.

 

   

Our estimated proved reserves are based on many assumptions that may turn out to be inaccurate. Any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves.

 

   

Our business is difficult to evaluate because we have a limited operating history.

 

   

The agreement governing our senior secured term loan contains covenants that may inhibit our ability to make certain investments, incur additional indebtedness or engage in certain other transactions, which could adversely affect our ability to meet our future goals.

 

   

Our level of indebtedness, including future indebtedness, could reduce our financial flexibility.

 

   

Our potential drilling locations are expected to be drilled over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling.

 

   

If we fail to realize the anticipated benefits of a significant acquisition, including the Ft. Trinidad acquisition, our results of operations may be lower than we expect.

 

 

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We are subject to complex federal, state, local and other laws and regulations, including environmental and human health and safety laws and regulations, which could adversely affect the timing, cost, manner or feasibility of conducting our operations and expose us to significant liabilities.

 

   

Certain of our directors, executive officers and other members of management and certain of our significant stockholders have direct economic interests in some of our properties, and their interests may not be aligned with our interests.

 

   

The concentration of our capital stock ownership by our largest stockholders will limit your ability to influence corporate matters.

 

This list is not exhaustive. Please read the full discussion of these risks and other risks under the heading “Risk Factors” beginning on page 15.

 

Implications of Being an Emerging Growth Company

 

As a company with less than $1.0 billion in revenue during its last fiscal year, we qualify as an “emerging growth company” as defined in the Jumpstart Our Business Startups Act of 2012, or the JOBS Act. An emerging growth company may take advantage of exemptions from various reporting requirements that are applicable to other public companies that are not “emerging growth companies.” These include:

 

   

an exemption from the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act relating to internal control over financial reporting;

 

   

reduced disclosure about the emerging growth company’s executive compensation arrangements; and

 

   

exemptions from the requirements of holding a non-binding advisory vote on executive compensation and shareholder approval of golden parachute arrangements.

 

We may take advantage of these reporting exemptions until we are no longer an emerging growth company. We will remain an “emerging growth company” until the earliest of the following:

 

   

the end of the fiscal year in which the fifth anniversary of the completion of this offering occurs;

 

   

the end of the first fiscal year in which the market value of our common stock that is held by non-affiliates is at least $700 million as of the end of the second quarter of such fiscal year;

 

   

the end of the first fiscal year in which we have total annual gross revenues of at least $1 billion; and

 

   

the date on which we have issued more than $1 billion in non-convertible debt securities in any rolling three-year period.

 

We expect to take advantage of some or all of these reduced reporting requirements, and if we do, the information that we provide to our stockholders may be different from information provided by other public companies. We have taken advantage of the reduced executive compensation disclosure requirements in this prospectus. Additionally, in this prospectus we have taken advantage of reduced financial reporting requirements available under the JOBS Act for an emerging growth company in the registration statement for its initial public offering. Specifically, we have provided only three years of selected financial data and only two years of audited financial statements of TreadStone.

 

Section 107 of the JOBS Act provides that an emerging growth company may take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. In other words, an emerging growth company may delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. However, we are choosing to “opt out” of the extended transition period, and as a result, we will comply with new or revised accounting standards on the relevant dates on which adoption of such standards is required for non-emerging growth companies. Section 107 of the JOBS Act provides that our decision to opt out of the extended transition period for complying with new or revised accounting standards is irrevocable.

 

 

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THE OFFERING

 

Issuer

Energy & Exploration Partners, Inc.

 

Common stock offered by us

             shares

 

Common stock offered by the selling stockholders

             shares

 

Common stock to be outstanding after this offering

             shares

 

Option to purchase additional shares

The underwriters have an option to purchase a maximum of              additional shares of common stock from us to cover sales by the underwriters of more than              shares. The underwriters may exercise this option at any time within 30 days from the date of this prospectus.

 

Use of proceeds

We expect to receive approximately $         million of net proceeds from the sale of the common stock offered by us, based upon an assumed initial public offering price of $         per share (the midpoint of the price range set forth on the cover page of this prospectus), after deducting underwriting discounts and estimated offering expenses payable by us. Each $1.00 increase (decrease) in the public offering price would increase (decrease) our net proceeds by approximately $         million.

 

  We intend to use the net proceeds we receive from this offering to:

 

   

repay the note, which we refer to as the Chesapeake note, described under “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Debt Facilities and Notes—Chesapeake Note”, which as of June 30, 2014 had a principal amount outstanding of approximately $20.3 million; and

 

   

fund a portion of our 2014 and 2015 capital expenditure budget for drilling and developing our leasehold acreage, acquire additional oil and natural gas leases, extend the expiration of our current leasehold acreage and acquire 3D seismic data.

 

  We will not receive any proceeds from the sale of shares by the selling stockholders. See “Use of Proceeds.”

 

Dividend policy

After this offering, we do not anticipate paying cash dividends on our common stock in the foreseeable future. See “Dividend Policy.”

 

Listing

We have applied to list our common stock on the New York Stock Exchange under the symbol “ENXP.”

 

Risk factors

See “Risk Factors” beginning on page 15 for a discussion of factors you should consider before deciding to purchase shares of our common stock.

 

 

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Unless otherwise indicated, all share information contained in this prospectus:

 

   

assumes that the underwriters’ option to purchase additional shares, granted by us, will not be exercised;

 

   

does not include              shares of common stock reserved for issuance under our 2012 Stock Incentive Plan;

 

   

gives effect to a     -for-1 stock split that we will effect immediately prior to the completion of this offering;

 

   

gives effect to the automatic conversion of outstanding warrants into              shares of our common stock at the completion of this offering on a net basis assuming an initial public offering price of $         per share; and

 

   

gives effect to the conversion of convertible notes into              shares of our common stock upon completion of this offering assuming the conversion of all convertible notes and an initial public offering price of $         per share. A $1.00 increase in the initial public offering price per share would decrease the number of shares issuable upon conversion of the convertible notes by              shares, and a $1.00 decrease in the initial public offering price per share would increase the number of shares issuable upon conversion of the convertible notes by              shares.

 

 

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Summary Historical and Pro Forma Consolidated Financial Data

 

Set forth below are our summary historical and pro forma consolidated financial data as of the dates and for the periods indicated. The summary historical consolidated financial data as of December 31, 2013 and 2012 and for the years ended December 31, 2013, 2012 and 2011 are derived from our audited consolidated financial statements included elsewhere in this prospectus. The summary historical condensed consolidated financial data as of June 30, 2014 and for the six months ended June 30, 2014 and 2013 are derived from our condensed unaudited consolidated financial statements included elsewhere in this prospectus, which in the opinion of our management, include all adjustments, consisting only of normal recurring adjustments, necessary for a fair statement of this information. Results of operations for the six months ended June 30, 2014 and 2013 are not necessarily indicative of the results of operations for the entire year or any future period.

 

The summary pro forma consolidated financial data as of and for the six months ended June 30, 2014 and for the year ended December 31, 2013 are derived from the unaudited pro forma combined and consolidated financial statements included elsewhere in this prospectus. The summary pro forma combined and consolidated balance sheet and statement of operations data give effect to the following transactions, which we refer to collectively as the Pro Forma Transactions, as if they had occurred on June 30, 2014 in the case of the unaudited pro forma combined and consolidated balance sheet data and on January 1, 2013 in the case of the unaudited pro forma combined and consolidated statement of operations data:

 

   

the Ft. Trinidad acquisition;

 

   

the issuance of the $375.0 million principal amount of convertible notes;

 

   

the borrowing of $775.0 million under the senior secured term loan;

 

   

the conversion of the convertible notes into shares of our common stock upon completion of this offering;

 

   

the issuance of the $18.0 million Chesapeake note;

 

   

the extinguishment of a previously outstanding credit facility that was repaid in April 2013 and the extinguishment of our senior unsecured notes; and

 

   

the automatic conversion of the outstanding warrants into              shares of our common stock upon completion of this offering.

 

The summary pro forma combined and consolidated statement of operations data do not include adjustments for historical revenues or expenses associated with the properties acquired in the Chesapeake acquisition described under “Business—Chesapeake Acquisition,” as the amounts were not material. The summary pro forma combined and consolidated financial data are not necessarily indicative of what our results of operations or financial position would have been if the Pro Forma Transactions had actually occurred on the dates indicated or of our future results of operations or financial position.

 

 

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The information set forth below should be read together with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the historical and pro forma financial statements and the notes thereto included elsewhere in this prospectus. The financial data included in this prospectus may not be indicative of our future results of operations, financial position and cash flows.

 

     Historical     Pro Forma  
     Year Ended
December 31,
    Six Months Ended
June 30,
    Year Ended
December 31,
    Six
Months
Ended
June 30,
 
     2011     2012     2013     2013     2014     2013     2014  
                       (unaudited)     (unaudited)  
     (in thousands)  

Statement of operations data:

              

Revenues

   $ —        $ 216      $ 16,437      $ 1,942      $ 21,248      $ 100,422      $ 118,889   

Operating expenses

     1,777        14,989        36,333        18,795        23,777        72,910        64,802   

Income (loss) from operations

     (1,777     (14,773     (19,896     (16,853     (2,529     27,512        54,087   

Net income (loss)

     (1,478     8,734        (21,767     (9,432     (3,282     (7,673     36,199   

 

     Historical      Pro Forma  
     As of December 31,      As of June 30,      As of June 30,  
             2011                      2012                     2013              2014      2014  
                         (unaudited)      (unaudited)  
     (in thousands)  

Balance sheet data:

             

Cash and cash equivalents

   $ 5,397       $ 10,228      $ 3,569       $ 2,706       $ 131,520   

Property, plant and equipment

     21,641         33,448        229,257         280,503         982,571   

Total assets

     27,968         68,074        243,573         296,473         1,140,402   

Long-term debt, net of discount

     9,928         14,191 (1)      168,336         224,985         775,926 (2) 

Total equity

     14,936         28,564        30,265         31,688      

 

(1)   Excludes $7.1 million reflected as current note payable.
(2)   Excludes $7.8 million reflected as current portion of long-term debt.

 

     Year Ended
December 31,
    Six Months Ended
June 30,
 
     2011     2012     2013     2013     2014  
                       (unaudited)  
     (in thousands)  

Other financial data:

          

Net cash provided by (used in) operating activities

   $ (1,004   $ (11,072   $ 19,946      $ (596   ($ 13,747

Net cash provided by (used in) investing activities

     (17,868     12,911        (164,482     (70,687     (41,912

Net cash provided by financing activities

     21,704        2,992        137,877        116,095        54,796   

Opening cash

     2,565        5,397        10,228        10,228        3,569   

Closing cash

     5,397        10,228        3,569        55,040        2,706   

 

 

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Summary Reserve Data

 

The following table presents summary data with respect to our estimated net proved oil and natural gas reserves as of December 31, 2013 and June 1, 2014, the estimated net proved reserves attributable to the properties acquired in the Ft. Trinidad acquisition as of June 1, 2014 and our estimated net proved oil and natural gas reserves as of June 1, 2014 giving pro forma effect to the Ft. Trinidad acquisition. For additional information regarding our reserves, see “Business—Our Operations—Estimated proved reserves.” The estimates of our reserves as of December 31, 2013 and June 1, 2014 and the estimates of the reserves attributable to the properties acquired in the Ft. Trinidad acquisition as of June 1, 2014 are based on reports prepared by Cawley, Gillespie & Associates, Inc., our independent reserve engineers. Reserve estimates were prepared in accordance with the rules and regulations of the SEC regarding oil and natural gas reserve reporting. All of the reserves shown in the table below are in the East Texas stacked play.

 

     As of
December 31,
2013(1)
    As of
June 1,
2014(1)
    Ft. Trinidad
Acquisition
as of
June 1,
2014(2)
    Pro Forma
as of
June 1,
2014
 

Proved developed reserves:

        

Oil (MBbl)

     1,947        1,898        6,754        8,652   

Natural gas (MMcf)(3)

     2,897        2,302        6,321        8,623   

Natural gas liquids (MBbl)

     —          257        1,059        1,316   

Equivalent (MBoe)

     2,430        2,538        8,866        11,405   

Proved undeveloped reserves(4):

        

Oil (MBbl)

     3,912        5,585        18,524        24,109   

Natural gas (MMcf)(3)

     4,292        3,308        16,171        19,479   

Natural gas liquids (MBbl)

     —          500        2,643        3,143   

Equivalent (MBoe)

     4,627        6,637        23,862        30,499   

Proved reserves:

        

Oil (MBbl)

     5,859        7,484        25,277        32,761   

Natural gas (MMcf)(3)

     7,188        5,610        22,492        28,102   

Natural gas liquids (MBbl)

     —          757        3,702        4,458   

Equivalent (MBoe)

     7,057        9,175        32,728        41,903   

Total proved developed reserves as a percent of total proved reserves

     34     28     27     27

Oil as a percent of total proved reserves

     83     82     77     78

PV-10 (in thousands)(5)

   $ 149,045      $ 205,719      $ 1,208,044      $ 1,413,763   

Proved developed PV-10 as a percent of total PV-10

     60     43     33     34

 

(1)   Our estimated proved reserves were determined using index prices for oil and natural gas without giving effect to derivative transactions, and were held constant throughout the life of the properties. The unweighted arithmetic average first-day-of-the-month prices for the twelve months ended June 1, 2014 and for the twelve months ended December 31, 2013 were $99.38/Bbl and $96.94/Bbl for oil, respectively, and $4.07/MMBtu and $3.67/MMBtu for natural gas, respectively. These prices were adjusted by well for gravity, quality, heating value, shrinkage, transportation and marketing. Including such adjustments, the prices as of June 1, 2014 and December 31, 2013 were $99.12/Bbl and $95.16/Bbl for oil, respectively, $3.76/Mcf and $3.39/Mcf for natural gas, respectively, and $28.22/Bbl for natural gas liquids as of June 1, 2014.
(2)  

Ft. Trinidad acquisition proved reserves were determined using the same index prices indicated above and the same adjustment procedure. Including such adjustments, the prices as of June 1, 2014 were $102.09/Bbl for oil, $4.53/Mcf for natural gas and $45.42/Bbl for natural gas liquids. Oil production from the properties

 

 

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acquired in the Ft. Trinidad acquisition benefited from favorable pricing in 2013, resulting in a higher average crude oil price differential than our other properties. Natural gas production from the properties acquired in the Ft. Trinidad acquisition benefited from materially different purchase contracts still in effect, transportation, heating value, and plant recoveries, resulting in a higher natural gas price differential than our other properties.

(3)   Includes immaterial amounts of natural gas liquids as of December 31, 2013.
(4)   As of June 1, 2014 includes 26 gross (25.5 net) proved undeveloped drilling locations in which we have an average working interest of 98.0% and an average net revenue interest of 76.5% and assumes average estimated drilling and completion costs of $6.1 million per well for us as of June 1, 2014. The Ft. Trinidad acquisition proved undeveloped net Mboe value as of June 1, 2014 includes 116 gross (105 net) vertical Buda-Rose locations with 22,602 Mboe, an average working interest of 90.4% and an average net revenue interest of 83.3% and average estimated drilling and completion costs of $2.6 million per well, as well as 29 gross (29 net) vertical Edwards locations.
(5)   PV-10 is a non-GAAP financial measure and is derived from the standardized measure of discounted future net cash flows (the Standardized Measure), which is the most directly comparable GAAP financial measure. PV-10 is equal to the Standardized Measure at the applicable date, before deducting estimated future income taxes, discounted at 10%. We believe that the presentation of PV-10 is relevant and useful to investors because it presents the relative monetary significance of our properties regardless of tax structure. Further, investors may utilize the measure as a basis for comparison of the relative size and value of our proved reserves to other companies. We use this measure when assessing the potential return on investment related to our oil and natural gas properties. However, PV-10 is not equal to, nor a substitute for, the Standardized Measure. Our PV-10 and the Standardized Measure do not purport to present the fair value of our proved reserves. See “—Reconciliation of PV-10 to the Standardized Measure” below.

 

Reconciliation of PV-10 to the Standardized Measure

 

The Standardized Measure represents the present value of estimated future cash inflows from proved reserves, less future development, production and income tax expenses, discounted at 10% per annum to reflect timing of future cash flows. The following table provides a reconciliation of PV-10 to the GAAP financial measure of the Standardized Measure as of December 31, 2013. We have not provided a reconciliation of PV-10 to the Standardized Measure as of June 1, 2014 as we have not prepared a Standardized Measure as of June 1, 2014:

 

     As of December 31,
2013
 
     (unaudited) (in thousands)  

Present value of estimated future net revenues (PV-10)

   $ 149,045   

Future income taxes, discounted at 10%

   $ (35,159
  

 

 

 

Standardized measure of discounted future net cash flows

   $ 113,886   
  

 

 

 

 

 

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RISK FACTORS

 

An investment in our common stock involves significant risks. You should carefully consider the risks described below together with the other information set forth in this prospectus before making an investment decision. Our business, financial condition or results of operations could be materially adversely affected by any of these risks. The trading price of our common stock could decline due to any of these risks, and you may lose all or part of your investment.

 

Risks Related to the Oil and Natural Gas Industry and Our Business

 

A substantial or extended decline in oil, natural gas and natural gas liquids prices may adversely affect our business, financial condition or results of operations and our ability to meet our capital expenditure obligations and financial commitments.

 

The prices we will receive for our oil, natural gas and natural gas liquids will significantly affect our revenue, profitability, access to capital and future rate of growth. Oil and natural gas are commodities and, therefore, their prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. Historically, the markets for oil and natural gas have been volatile. For example, for the four years ended December 31, 2013, the NYMEX—WTI oil price ranged from a high of $113.93 per Bbl to a low of $66.88 per Bbl, while the NYMEX—Henry Hub natural gas price ranged from a high of $6.01 per MMBtu to a low of $1.91 per MMBtu. These markets will likely continue to be volatile in the future. The prices we will receive for our production, and the levels of our production, will depend on numerous factors beyond our control. These factors include the following:

 

   

worldwide and regional economic conditions impacting the global supply and demand for oil and natural gas;

 

   

the actions of the Organization of Petroleum Exporting Countries, or OPEC;

 

   

the price and quantity of imports of foreign oil and natural gas;

 

   

political conditions in or hostilities in oil-producing and natural gas-producing regions and related sanctions, including current conflicts in the Middle East and conditions in Africa, South America, Russia and Ukraine;

 

   

the level of global oil and domestic natural gas exploration and production;

 

   

the level of global oil and domestic natural gas inventories;

 

   

prevailing prices on local oil and natural gas price indexes in the areas in which we operate;

 

   

localized supply and demand fundamentals and gathering, processing and transportation availability;

 

   

weather conditions and natural disasters;

 

   

domestic and foreign governmental regulations;

 

   

authorization of exports from the United States of liquefied natural gas or oil;

 

   

speculation as to the future price of oil and the speculative trading of oil and natural gas futures contracts;

 

   

price and availability of competitors’ supplies of oil and natural gas;

 

   

technological advances affecting energy consumption; and

 

   

the price and availability of alternative fuels.

 

Lower oil and natural gas prices will reduce our cash flows and our borrowing ability. Our business plan requires substantial additional capital, which we may be unable to raise on acceptable terms in the future, which may in turn limit our ability to develop our exploration and production plans. A substantial or extended decline in oil and natural gas prices may also reduce the amount of oil and natural gas that we can produce economically.

 

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Drilling for and producing oil and natural gas are high risk activities with many uncertainties that could adversely affect our business, financial condition or results of operations.

 

Our future financial condition and results of operations will depend on the success of our exploration, development and production activities. Our oil and natural gas exploration and production activities are subject to numerous risks beyond our control, including the risk that drilling will not result in commercially viable oil or natural gas production. Our decisions to purchase, explore, develop or otherwise exploit drilling locations or properties will depend in part on the evaluation of data obtained through geophysical and geological analyses, production data and engineering studies, the results of which are often inconclusive or subject to varying interpretations. Our costs of drilling, completing and operating wells are uncertain before drilling commences. In addition, the application of new techniques for horizontal fracture stimulation and completion, may make it more difficult to accurately estimate these costs. Overruns in budgeted expenditures are common risks that can make a particular project uneconomic. Further, many factors may curtail, delay or cancel our scheduled drilling projects, including the following:

 

   

increases in the costs of, shortages of or delays in obtaining rigs, equipment, qualified personnel or other services;

 

   

facility or equipment malfunctions;

 

   

unexpected drilling conditions;

 

   

pressure or irregularities in geological formations;

 

   

adverse weather conditions;

 

   

reductions in oil and natural gas prices;

 

   

delays imposed by or resulting from compliance with permitting and other regulatory requirements;

 

   

proximity to and capacity of gathering, processing and transportation facilities;

 

   

availability of water;

 

   

compliance with changing well integrity, environmental, health and safety, and other regulatory requirements;

 

   

environmental hazards, such as natural gas leaks, oil or salt water spills, pipeline and tank ruptures and unauthorized discharges of toxic gases or other pollutants into the environment, including the subsurface;

 

   

lost or damaged oilfield development and service tools;

 

   

pipe or cement failures, casing collapses or other downhole failures;

 

   

loss of drilling fluid circulation;

 

   

fires, blowouts, surface craterings and explosions;

 

   

uncontrollable flows of oil, natural gas or well fluids;

 

   

loss of leases due to incorrect payment of royalties;

 

   

title problems; and

 

   

limitations in the market for oil and natural gas.

 

Our business plan requires additional capital, which we may be unable to raise on acceptable terms in the future, which may in turn limit our ability to pursue our exploration and production plans.

 

We expect our capital outlays and operating expenditures to increase substantially over the next several years as we expand our operations. Exploration and production plans are expensive, and we expect that we will need to raise substantial additional capital, through future private or public equity offerings, strategic alliances or debt financing.

 

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Our future capital requirements will depend on many factors, including:

 

   

the scope, rate of progress and cost of our exploration and production activities;

 

   

oil and natural gas prices;

 

   

our ability to locate and acquire hydrocarbon reserves;

 

   

our ability to produce oil or natural gas from those reserves;

 

   

the terms and timing of any drilling and other production-related arrangements that we may enter into;

 

   

fluctuations in our working capital needs;

 

   

interest payments and debt service requirements;

 

   

prevailing economic conditions;

 

   

the ability and willingness of banks and other lenders to lend to us;

 

   

our ability to access the equity and debt capital markets;

 

   

the cost and timing of governmental permits or approvals; and

 

   

the effects of competition by larger companies operating in the oil and natural gas industry.

 

We currently intend to finance our future capital expenditures primarily with the net proceeds from the this offering, cash on hand, cash flows provided by operating activities, proceeds from asset divestitures and additional borrowings under our senior secured term loan, if available. We expect the net proceeds from this offering, cash on hand and cash flows provided by operating activities will fully fund our $139 million capital expenditures budget for the last six months of 2014 and all of our 2015 capital expenditures budget. We expect that we will need to seek additional equity or debt financing to fund capital expenditures in excess of our current budget, which financing may not be available on favorable terms, or at all. Subject to obtaining the participation of existing or new lenders and other conditions, we may incur additional loans of up to $175 million under our senior secured term loan. We may not be able to obtain the participation of existing or new lenders or be able to satisfy the other conditions for additional loans under the senior secured term loan. Further, our cash flows from operating activities are uncertain and may be less than expected, as revenues from production are dependent on the success of our exploration and development activities. If additional financing is not available, we would be forced to curtail or delay our planned capital expenditures. The issuance of additional debt may require that a larger portion of our cash flows provided by operating activities be used for the payment of principal and interest on our debt, thereby reducing our ability to use cash flows to fund working capital, capital expenditures and acquisitions. If we succeed in selling additional equity securities to raise funds, at such time the ownership percentage of our existing stockholders would be diluted, and new investors may demand rights, preferences or privileges senior to those of our common stock. If we raise additional capital through debt financing, the financing may involve covenants that restrict our business activities. If we choose to farm-out interests in our prospects, we may lose operating control over such prospects.

 

If we are not successful in raising additional capital, we may be unable to continue our exploration and production activities or successfully exploit our oil and natural gas properties, and we may lose the rights to develop these oil and natural gas properties upon the expiration of our leases.

 

Drilling locations that we decide to drill may not yield oil in commercial quantities or quality, or at all.

 

We describe some of our potential drilling locations and our plans to explore those drilling locations in this prospectus. Our potential drilling locations are in various stages of evaluation, ranging from locations that are ready to drill to locations that will require substantial additional interpretation. There is no way to predict in advance of drilling and testing whether any particular location will yield oil or natural gas in sufficient quantities to recover drilling or completion costs or to be economically viable. The use of technologies and the study of

 

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producing fields in the same area will not enable us to know conclusively prior to drilling whether oil or natural gas will be present or, if present, whether oil or natural gas will be present in sufficient quantities to be economically viable. Even if sufficient amounts of oil or natural gas exist, we may damage the potentially productive hydrocarbon bearing formation or experience mechanical difficulties while drilling or completing the well, resulting in a reduction in production from the well or abandonment of the well. If we drill additional wells that we identify as dry holes, our drilling success rate may decline and materially harm our business. We cannot assure you that the analogies we draw from available data from other wells, more fully explored locations or producing fields will be applicable to our potential drilling locations. Further, drilling costs and initial production rates reported by other operators in the areas in which our properties are located may not be indicative of future or long-term drilling costs or production rates. Ultimately, the cost of drilling, completing and operating any well is often uncertain, and new wells may not be productive.

 

We may terminate our drilling program for a prospect if data, information, studies and previous reports indicate that the possible development of our prospect is not commercially viable and, therefore, does not merit further investment. If a significant number of our prospects do not prove to be successful, our business, financial condition and results of operations will be materially adversely affected.

 

We have a limited operating history and our future performance is uncertain.

 

We are a company in the initial stages of exploration, development and exploitation of our leasehold acreage. Companies in their initial stages of development face substantial business risks and may suffer significant losses. We have generated substantial net losses and negative cash flows from operating activities since we adopted a business strategy to develop our undeveloped leasehold acreage and expect to continue to incur substantial net losses from operating activities until our production increases. In considering an investment in our securities, you should consider that there is only limited historical and financial operating information available upon which to base your evaluation of our performance. We face challenges and uncertainties in financial planning as a result of the unavailability of historical data and uncertainties regarding the nature, scope and results of our future activities. These challenges may be magnified as a result of the Ft. Trinidad acquisition. New companies must develop successful business relationships, establish operating procedures, hire staff, install management information and other systems, establish facilities and obtain licenses, as well as take other measures necessary to conduct their intended business activities. We may not be successful in implementing our business strategies or in completing the development of the infrastructure necessary to conduct our business as planned. In the event that one or more of our drilling programs is not completed or is delayed or terminated, our operating results will be adversely affected and our operations will differ materially from the activities described in this prospectus. As a result of industry factors or factors relating specifically to us, we may have to change our methods of conducting business, which may cause a material adverse effect on our results of operations and financial condition. The uncertainty and risks described in this prospectus may impede our ability to economically find, develop, exploit and acquire oil and natural gas reserves. As a result, we may not be able to achieve or sustain profitability or positive cash flows provided by our operating activities in the future.

 

The agreement governing the senior secured term loan contains covenants that may inhibit our ability to make certain investments, incur additional indebtedness or engage in certain other transactions, which could adversely affect our ability to meet our future goals.

 

The agreement governing the senior secured term loan contains covenants that, among other things, restrict:

 

   

our investments, loans and advances and the payment of dividends and other restricted payments;

 

   

our incurrence of additional indebtedness;

 

   

the granting of liens other than certain permitted liens;

 

   

mergers, consolidations and sales of all or a substantial part of our business or properties; and

 

   

the sale of assets (other than production sold in the ordinary course of business).

 

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These covenants may restrict our ability to expand or pursue our business strategies. The agreement also contains financial covenants. The breach of any of these covenants could result in a default under the senior secured term loan. If an event of default occurs, the lenders could elect to declare all amounts borrowed, together with accrued interest, to be due and payable. If we were unable to repay such borrowings or interest, our lenders under the senior secured term loan could proceed against their collateral. If our indebtedness were to be accelerated, our assets may not be sufficient to repay in full such indebtedness.

 

Our level of indebtedness, which may increase, could reduce our financial flexibility.

 

As of June 30, 2014, on a pro forma basis giving effect to the Pro Forma Transactions described under “Prospectus Summary—Summary Historical and Pro Forma Consolidated Financial Data” and giving further effect to this offering and the use of a portion of the net proceeds of this offering to repay the Chesapeake note in full, we would have had outstanding indebtedness of approximately $775 million, consisting of the senior secured term loan. In the future, we may incur significant indebtedness in order to develop our properties or to make future acquisitions. The terms of our senior secured term loan limit our ability to incur additional indebtedness, but those limitations are subject to significant exceptions.

 

Our level of indebtedness could affect our operations in several ways, including the following:

 

   

a significant portion of our cash flows will be used to service our indebtedness;

 

   

a high level of debt increases our vulnerability to general adverse economic and industry conditions;

 

   

the covenants contained in the agreement governing our senior secured term loan will, and the terms of our future indebtedness may, limit our ability to borrow additional funds, dispose of assets, pay dividends and make certain investments;

 

   

our debt covenants may also affect our flexibility in planning for, and reacting to, changes in the economy and in our industry;

 

   

a high level of debt may place us at a competitive disadvantage compared to our competitors that are less leveraged and, therefore, may be able to take advantage of opportunities that our indebtedness would prevent us from pursuing; and

 

   

a high level of debt may impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions, general corporate expenses or other purposes.

 

A high level of indebtedness would increase the risk that we may default on our debt obligations. Our ability to meet our debt obligations and to reduce our level of indebtedness will depend on our future performance.

 

General economic conditions, oil and natural gas prices and financial, business and other factors affect our operations and our future performance. Many of these factors are beyond our control. We may not be able to generate sufficient cash flows to pay the interest on our debt and future working capital, borrowings or equity financing may not be available to pay or refinance such debt. Factors that will affect our ability to raise cash through an offering of our capital stock or a refinancing of our debt include financial market conditions, the value of our assets and our performance at the time we need capital.

 

Part of our strategy involves drilling in existing or emerging plays using some of the latest available horizontal drilling and completion techniques. The results of our planned exploratory drilling in these plays are subject to drilling and completion technique risks, and drilling results may not meet our expectations for reserves or production. As a result, we may incur material write-downs and the value of our undeveloped acreage could decline if drilling results are unsuccessful.

 

Our operations in the East Texas stacked play involve utilizing the latest drilling and completion techniques in order to maximize cumulative recoveries and therefore generate the highest possible returns. Risks that we

 

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may face while drilling include, but are not limited to, landing our well bore in the desired drilling zone, staying in the desired drilling zone while drilling horizontally through the formation, running our casing the entire length of the well bore and being able to run tools and other equipment consistently through the horizontal well bore. Risks that we may face while completing our wells include, but are not limited to, being able to fracture stimulate the planned number of stages, being able to run tools the entire length of the well bore during completion operations, staying in the desired formation when fracturing, and successfully cleaning out the well bore after completion of the final fracture stimulation stage.

 

The results of our drilling in new or emerging formations will be more uncertain initially than drilling results in areas that are more developed and have a longer history of established production. Newer or emerging formations and areas have limited or no production history and consequently we are less able to predict future drilling results in these areas.

 

Ultimately, the success of these drilling and completion techniques can only be evaluated over time as more wells are drilled and production profiles are established over a sufficiently long time period. If our drilling results are less than anticipated or we are unable to execute our drilling program because of capital constraints, lease expirations, access to gathering systems and limited takeaway capacity or otherwise, and/or natural gas and oil prices decline, the return on our investment in these areas may not be as attractive as we anticipate. Further, as a result of any of these developments we could incur material write-downs of our oil and natural gas properties and the value of our undeveloped acreage could decline in the future.

 

Our properties are geographically concentrated, making us disproportionately vulnerable to risks associated with operating in our areas of operation.

 

Our properties are geographically concentrated. All of our acreage is located in three basins: the East Texas stacked play, the Permian Basin and the DJ Basin. The majority of our acreage is located in the East Texas stacked play, our primary area of operation. As a result of this concentration, we may be disproportionately exposed to the impact of events or circumstances in these areas (particularly in the East Texas stacked play) such as regional supply and demand factors, delays or interruptions of production from wells caused by governmental regulation, gathering, processing or transportation capacity constraints, market limitations, or interruption of the gathering, processing or transportation of oil, natural gas or natural gas liquids.

 

If oil and natural gas prices decrease, our development efforts are unsuccessful or our capital and operating costs increase substantially, we may be required to take write-downs of the carrying values of our oil and natural gas properties.

 

We employ the full cost method of accounting for our oil and natural gas properties which, among other things, imposes limits to the capitalized cost of our assets. The capitalized cost pool cannot exceed the net present value of the underlying oil and natural gas reserves. We will review our future proved oil and natural gas properties for impairment whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. Based on specific circumstances at the time of prospective impairment reviews, and the continuing evaluation of development plans, production data, economics and other factors, we may be required to write down the carrying value of our oil and natural gas properties, which may result in a decrease in the amount available under future credit facilities. A write down constitutes a non-cash charge to earnings. We may incur impairment charges in the future, which could have a material adverse effect on our results of operations for the periods in which such charges are taken.

 

Our estimated proved reserves are based on many assumptions that may turn out to be inaccurate. Any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves.

 

The process of estimating oil and natural gas reserves is complex. It requires interpretations of available technical data and many assumptions, including assumptions relating to current and future economic conditions

 

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and commodity prices. Any significant inaccuracies in these interpretations or assumptions could materially affect the estimated quantities and present value of reserves shown in this prospectus. See “Business—Our Operations—Estimated proved reserves” for information about our estimated oil and natural gas reserves.

 

In order to prepare estimates of our proved reserves, Cawley, Gillespie & Associates, Inc., our independent reserve engineers, must project production rates and the timing of development expenditures as well as analyze available geological, geophysical, production and engineering data. The extent, quality and reliability of this data can vary. The process also requires economic assumptions about matters such as oil and natural gas prices, drilling and operating expenses, capital expenditures, taxes and availability of funds. Although the reserve information contained in this prospectus is prepared by our independent reserve engineers, estimates of oil and natural gas reserves are inherently imprecise.

 

Actual future production, oil and natural gas prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable oil and natural gas reserves will vary from our estimates. Any significant variance could materially affect the estimated quantities and present value of reserves shown in this prospectus. In addition, we may adjust estimates of proved reserves to reflect production history, results of exploration and development, prevailing oil and natural gas prices and other factors, many of which are beyond our control.

 

The present value of future net revenues from our proved reserves will not necessarily be the same as the current market value of our estimated oil and natural gas reserves.

 

You should not assume that the present value of future net revenues from our proved reserves is the current market value of our estimated oil and natural gas reserves. As required by SEC rules and regulations, we based the estimated discounted future net revenues from proved reserves as of December 31, 2012, December 31, 2013 and June 1, 2014 on the unweighted arithmetic average of the first-day-of-the-month price for the preceding twelve months without giving effect to derivative transactions as well as operating and development costs being incurred at the end of the reporting period. Consequently, it may not reflect the prices ordinarily received or that will be received for oil and natural gas production because of seasonal price fluctuations or other varying market conditions, nor may it reflect the actual costs that will be required to produce or develop the oil and natural gas properties. Accordingly, estimates included herein of future net cash flows may be materially different from the future net cash flows that are ultimately received. In addition, the ten percent discount factor, which is required by the SEC to be used in calculating discounted future net cash flows for reporting purposes, may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with us or the oil and gas industry in general. Therefore, the estimates of discounted future net cash flows, Standardized Measure and PV-10 in this prospectus should not be construed as accurate estimates of the current market value of our proved reserves. Actual future net revenues from our oil and natural gas properties will be affected by factors such as:

 

   

actual prices we receive for oil and natural gas;

 

   

actual cost of development and production expenditures;

 

   

the amount and timing of actual production; and

 

   

changes in governmental regulations or taxation.

 

Actual future prices and costs may differ materially from those used in the present value estimates included in this prospectus.

 

Unless we replace our reserves with new reserves and develop those reserves, our future reserves and production will decline, which would adversely affect our future cash flows and results of operations.

 

Producing hydrocarbon reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Unless we conduct successful ongoing exploitation,

 

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development and exploration activities or continually acquire properties containing reserves, our reserves will decline as reserves are produced. Our future oil and natural gas reserves and production, and therefore our future cash flow and results of operations, are highly dependent on our success in efficiently developing and exploiting our current reserves and economically finding or acquiring additional recoverable reserves. We may not be able to develop, exploit, find or acquire sufficient additional reserves to replace our production. If we are unable to replace our production, the value of our reserves will decrease, and our business, financial condition and results of operations would be adversely affected.

 

Our business depends on oil and natural gas gathering and transportation facilities owned by third parties.

 

The marketability of our oil and natural gas production will depend in part on the availability, proximity and capacity of gathering, processing and pipeline systems owned by third parties. The unavailability of, or lack of, available capacity on these systems and facilities could result in the shut-in of producing wells or the delay, or discontinuance, of development plans for properties. We do not expect to purchase firm transportation on third-party facilities and, therefore, we expect the transportation of our production to be generally interruptible in nature and lower in priority to those having firm transportation arrangements. Federal and state regulation of oil and natural gas production and transportation, tax and energy policies, changes in supply and demand, pipeline pressures or quality standards, pipeline integrity requirements, damage to or destruction of pipelines and general economic conditions could adversely affect our ability to produce, gather and transport our oil and natural gas.

 

The disruption of third-party facilities due to maintenance, force majeure and/or weather could also negatively impact our ability to market and deliver our products. We have no control over when or if such facilities are restored by third-party owners or operators, or what prices will be charged for their services. A total shut-in of production resulting from the acts or omissions of third-party transportation providers, or circumstances affecting third-party transportation facilities, could materially affect us due to a lack of cash flow, and if a substantial portion of the price risk associated with production volumes is mitigated through commodity derivative instruments at lower than market prices, those commodity derivative settlements would have to be paid from borrowings absent sufficient cash flow.

 

The unavailability or high cost of additional drilling rigs, equipment, supplies, personnel and oilfield services could adversely affect our ability to execute our exploration and development plans within our budget and on a timely basis.

 

Shortages or the high cost of drilling rigs, equipment, supplies, personnel or oilfield services, particularly in the East Texas stacked play, could delay or adversely affect our exploration and development operations or cause us to incur significant expenditures that are not provided for in our capital budget, which could have a material adverse effect on our business, financial condition or results of operations. The cost to develop our projects has not been fixed and remains dependent upon a number of factors, including the completion of detailed cost estimates and final engineering, contracting and procurement costs. Our drilling and operation schedules may not proceed as planned and may experience delays or cost overruns. Any delays may increase the costs of the projects, requiring additional capital, and such capital may not be available on a timely and cost-effective fashion.

 

Market conditions or operational impediments may hinder our access to oil and natural gas markets or delay our production.

 

Market conditions or the unavailability of satisfactory oil and natural gas gathering, transportation and processing arrangements may hinder our access to oil and natural gas markets or delay our production. The availability of a ready market for our oil and natural gas production will depend on a number of factors, including the demand for and supply of oil and natural gas and the proximity of reserves to pipelines and terminal facilities. Our ability to market our production will depend, in substantial part, on the availability and capacity of gathering systems, processing and pipelines facilities owned and operated by third-parties. Our failure to obtain such

 

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services on acceptable terms could materially harm our business. We may be required to shut in wells due to lack of a market or inadequacy or unavailability of oil or natural gas pipelines or gathering system capacity. If our production becomes shut-in for any of these or other reasons, we would be unable to realize revenue from those wells until other arrangements were made to deliver the products to market.

 

We may incur substantial losses or be subject to substantial liability claims as a result of our oil and natural gas operations. Additionally, we may not be insured for, or our insurance may be inadequate to protect us against, these risks.

 

Our oil and natural gas exploration and production activities are subject to the operating risks associated with drilling for and producing oil and natural gas, including the possibility of:

 

   

environmental hazards, such as uncontrolled flows of oil, natural gas, brine, well fluids, toxic gas or other pollution into the environment, including groundwater contamination;

 

   

abnormally pressured formations;

 

   

mechanical difficulties, such as stuck oilfield drilling and service tools and casing collapse;

 

   

fires, explosions and ruptures of pipelines;

 

   

personal injuries and death; and

 

   

natural disasters.

 

Any of these risks could adversely affect our ability to conduct operations or result in substantial losses to us as a result of:

 

   

injury or loss of life;

 

   

damage to and destruction of property, natural resources or equipment;

 

   

pollution or other environmental damage;

 

   

regulatory investigations or penalties;

 

   

suspension of our operations; or

 

   

repairs or remediation costs.

 

We are not insured against all risks. Losses and liabilities arising from uninsured and underinsured events could materially and adversely affect our business, financial condition or results of operations. We may elect not to obtain insurance if we believe that the cost of available insurance is excessive relative to the risks presented. In addition, pollution and environmental risks generally are not fully insurable. The occurrence of an event that is not fully covered by insurance could have a material adverse effect on our business, financial condition and results of operations.

 

Our potential drilling locations are expected to be drilled over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling. In addition, we may not be able to raise the substantial amount of capital that would be necessary to drill a substantial portion of our potential drilling locations.

 

We have provided information regarding potential drilling locations on our existing acreage. Our ability to drill and develop these locations is subject to a number of uncertainties, including the availability of capital, seasonal conditions, regulatory approvals, availability of drilling services and equipment, lease expirations, gathering systems, processing marketing and pipeline transportation constraints, oil and natural gas prices, drilling and production costs, drilling results and other factors. Additionally, our leases will expire if, prior to expiration of the initial term of such leases, we do not meet the production levels in the leases to hold the

 

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acreage. Because of these uncertainties and the potential for losing acreage where we have insufficient production to hold the acreage, we do not know if the potential drilling locations will ever be drilled or if we will be able to produce oil or natural gas from these or any other potential drilling locations. Pursuant to SEC rules and guidance, subject to limited exceptions, proved undeveloped reserves may only be booked if they relate to wells scheduled to be drilled within five years of the date of booking. SEC rules and guidance may limit our potential to book proved undeveloped reserves as we pursue our drilling program.

 

Our acreage must be drilled before lease expiration, generally within three to five years, in order to hold the acreage by production. In the highly competitive market for acreage, failure to drill sufficient wells in order to hold acreage will result in a substantial lease renewal cost, or if renewal is not feasible, loss of our lease and prospective drilling opportunities.

 

Our leases on oil and natural gas properties typically have a primary term of three to five years, after which they expire unless, prior to expiration, production is established within the spacing units covering the undeveloped acres. As of July 31, 2014, we had leases representing 5,923 net acres expiring in 2014, 16,906 net acres expiring in 2015, 16,003 net acres expiring in 2016 and 24,402 net acres expiring thereafter, assuming that we exercise all available lease extension options. If our extension options expire and we have to renew such leases on new terms, we could incur significant cost increases, and we may not be able to renew such leases on commercially reasonable terms or at all. In addition, on certain portions of our acreage, third-party leases become immediately effective if our leases expire. As such, our actual drilling activities may materially differ from our current expectations, which could adversely affect our business.

 

We are not the operator on a portion of our acreage, and, therefore, we will not be able to control the timing of exploration or development efforts, associated costs, or the rate of production of any non-operated assets.

 

Although we are the operator on the majority of our acreage, we are not the operator on approximately 13,580 net acres in the East Texas stacked play. As we carry out our exploration and development programs in the future, we may enter into arrangements with respect to existing or future drilling locations that result in additional drilling locations being operated by others. As a result, we may have limited ability to exercise influence over the operations of the drilling locations operated by our partners. Dependence on the operator could prevent us from realizing our target returns for those locations. The success and timing of exploration and development activities operated by our partners will depend on a number of factors that will be largely outside of our control, including:

 

   

the timing and amount of capital expenditures;

 

   

the operator’s expertise and financial resources;

 

   

the approval of other participants in drilling wells;

 

   

the selection of technology; and

 

   

the rate of production of reserves, if any.

 

This limited ability to exercise control over the operations of some of our drilling locations may cause a material adverse effect on our results of operations and financial condition.

 

Our use of 3D seismic data is subject to interpretation and may not accurately identify the presence of oil and natural gas, which could adversely affect the results of our drilling operations.

 

Even when properly used and interpreted, 3D seismic data and visualization techniques are only tools used to assist geologists in identifying subsurface structures and hydrocarbon indicators and do not enable the interpreter to know whether hydrocarbons are in fact present in those structures. In addition, the use of 3D seismic and other advanced technologies requires greater predrilling expenditures that traditional drilling strategies, and we could incur losses as a result of such expenditures. As a result, our drilling activities may not be successful or economical.

 

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Our operations are substantially dependent on the availability of water. Restrictions on our ability to obtain water may have an adverse effect on our financial condition, results of operations and cash flows.

 

Water is an essential component of deep shale oil and natural gas production during both the drilling and hydraulic fracturing processes. According to the Lower Colorado River Authority, during 2011, Texas experienced the lowest inflows of water of any year in recorded history, and inflows remained below average through July 2012. As a result of this severe drought, some local water districts have begun restricting the use of water subject to their jurisdiction for hydraulic fracturing in order to protect local water supply. If we are unable to obtain water to use in our operations from local sources, we may be unable to economically produce oil and natural gas, which could have an adverse effect on our financial condition, results of operations and cash flows.

 

We are subject to complex federal, state, local and other laws and regulations that could adversely affect the timing, cost, manner or feasibility of conducting our operations and expose us to significant liabilities.

 

Our ownership and operation of oil and natural gas properties are subject to complex and stringent laws and regulations. In order to conduct our operations in compliance with these laws and regulations, we must obtain and maintain numerous permits, approvals and certificates from various federal, state and local governmental authorities. We may experience delays in receiving such permits, approvals and certificates. Delays in permitting could result in delays in execution of our drilling and development program. We may incur substantial costs in order to maintain compliance with existing laws and regulations. In addition, our costs of compliance may increase if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to our operations. Such changes could have a material adverse effect on our business, financial condition and results of operations. Failure to comply with laws and regulations applicable to our operations, including any evolving interpretation and enforcement by governmental authorities, could have a material adverse effect on our business, financial condition and results of operations.

 

See “Business—Regulation of the Oil and Natural Gas Industry” for a further description of the laws and regulations that affect us.

 

Restrictions on drilling activities intended to protect certain species of wildlife may adversely affect our ability to conduct drilling activities in some of the areas where we operate.

 

Oil and natural gas operations in our operating areas can be adversely affected by seasonal or permanent restrictions on drilling activities designed to protect various wildlife and habitat. Seasonal restrictions may limit our ability to operate in protected areas and can intensify competition for drilling rigs, oilfield equipment, services, supplies and qualified personnel, which may lead to periodic shortages when drilling is allowed. These constraints and the resulting shortages or high costs could delay our operations and materially increase our operating and capital costs. Permanent restrictions imposed to protect species and habitat could prohibit drilling in certain areas or require the implementation of expensive mitigation measures.

 

The Endangered Species Act, or ESA, prohibits the harming of endangered or threatened species, provides for habitat protection and imposes stringent penalties for noncompliance. Complying with these protections provided for threatened or endangered species could cause us to incur increased costs arising from species protection measures or could result in limitations, delays or prohibitions on our exploration and production activities that could have an adverse impact on our ability to develop and produce our reserves. Moreover, as a result of a settlement approved by the U.S. District Court for the District of Columbia on September 9, 2011, the U.S. Fish and Wildlife Service, or FWS, is required to consider listing numerous species as endangered under the ESA. For example, on March 27, 2014, the FWS announced the listing of the lesser prairie chicken, whose habitat is over a five-state region, including Texas where we operate, as a threatened species under the ESA. However, the FWS also announced a final rule that will limit regulatory impacts on landowners and businesses from the listing if those landowners and businesses have entered into certain range-wide conservation planning agreements, such as those developed by the Western Association of Fish and Wildlife Agencies, or WAFWA,

 

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pursuant to which such parties agreed to take steps to protect the lesser prairie chicken’s habitat and to pay a mitigation fee if its actions harm the lesser prairie chicken’s habitat. The final designation of previously unprotected species in areas where we operate as threatened or endangered could cause us to incur increased costs arising from species protection measures or could result in limitations, delays or prohibitions on our exploration and production activities that could have an adverse impact on our ability to develop and produce our reserves.

 

Our operations are subject to environmental and worker health and safety laws and regulations that may expose us to significant costs and liabilities.

 

Our ownership and operation of oil and natural gas properties are subject to stringent and complex federal, state and local laws and regulations governing worker health and safety aspects of our operations, the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations may impose numerous obligations that are applicable to our operations including the acquisition of permits before conducting drilling, underground injection or other regulated activities; the restriction of types, quantities and concentration of materials that can be released into the environment; the limitation or prohibition of drilling activities on certain lands lying within wilderness, wetlands and other protected areas; the application of specific health and safety criteria addressing worker protection; and the imposition of substantial liabilities for pollution resulting from operations. Numerous governmental authorities, such as the U.S. Environmental Protection Agency, or the EPA, and analogous state agencies have the power to enforce compliance with these laws and regulations and the permits issued under them, oftentimes requiring difficult and costly actions. Failure to comply with these laws and regulations may result in the assessment of administrative, civil or criminal penalties; the imposition of investigatory or remedial obligations; and the issuance of injunctions limiting or preventing some or all of our operations.

 

There is inherent risk of incurring significant environmental costs and liabilities in the performance of our operations due to our handling of petroleum hydrocarbons and wastes, because of air emissions and wastewater discharges related to our operations, and as a result of historical industry operations and waste disposal practices.

 

Under certain environmental laws and regulations, we could be subject to joint and several, strict liability for the removal or remediation of previously released materials or property contamination regardless of whether we were responsible for the release or contamination or whether the operations were in compliance with all applicable laws at the time those actions were taken. Private parties, including the owners of properties upon which our wells are drilled and facilities where our petroleum hydrocarbons or wastes are taken for reclamation or disposal, may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property or natural resource damage. In addition, the risk of accidental spills or releases could expose us to significant liabilities that could have a material adverse effect on our financial condition or results of operations. Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent or costly well drilling, construction, completion or water management activities, or waste handling, storage, transport, disposal or cleanup requirements could require us to make significant expenditures to attain and maintain compliance and may otherwise have a material adverse effect on our own results of operations, competitive position or financial condition. We may not be able to recover some or any of these costs from insurance.

 

Climate change laws and regulations restricting emissions of “greenhouse gases” could result in increased operating costs and reduced demand for the oil and natural gas that we produce while the physical effects of climate change could disrupt our production and cause us to incur significant costs in preparing for or responding to those effects.

 

On December 15, 2009, the EPA published its findings that emissions of carbon dioxide, methane and other “greenhouse gases” present an endangerment to human health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the Earth’s atmosphere and other climatic changes.

 

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These findings by the EPA have allowed the agency to proceed with the adoption and implementation of regulations restricting emissions of greenhouse gases under existing provisions of the federal Clean Air Act.

 

Among other things, EPA regulations now require specified large greenhouse gas emitters in the United States, including companies in the energy industry, to annually report those emissions. Additionally, starting in 2011, new sources or modifications of existing sources of significant quantities of greenhouse gas emissions that are already subject to regulation as major sources of conventional pollutants are required to obtain permits—and to use best available control technology to control those emissions—pursuant to the Clean Air Act as a prerequisite to the development of that greenhouse gas emissions source. While these regulations have not to date materially affected our company, such regulations may over time require us to incur costs to reduce emissions of greenhouse gases associated with our operations or could adversely affect demand for the oil and natural gas we produce.

 

Additionally, from time to time over the past several years, the U.S. Congress has considered legislation to restrict or regulate emissions of greenhouse gases. It presently appears unlikely that comprehensive climate legislation will be passed by either house of Congress in the near future, although energy legislation and other initiatives continue to be proposed that may be relevant to greenhouse gas emissions issues. In addition, a number of the states, either individually or through multi-state regional initiatives, address greenhouse gas emissions primarily through the development of emission inventories or regional greenhouse gas cap and trade programs. Although most of the state-level initiatives have to date been focused on large sources of greenhouse gas emissions, such as electric power plants, it is possible that smaller sources could become subject to greenhouse gas-related regulation. Depending on the particular program, we could be required to control emissions or to purchase and surrender allowances for greenhouse gas emissions resulting from our operations. Any future federal laws or implementing regulations that may be adopted to address greenhouse gas emissions could require us to incur increased operating costs and could adversely affect demand for the oil and natural gas we produce.

 

Finally, it should be noted that some scientists have concluded that increasing concentrations of greenhouse gases in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, floods and other climatic events. If any such effects were to occur, they could have an adverse effect on our exploration and production operations. Significant physical effects of climate change could also have an indirect effect on our financing and operations by disrupting the transportation or process-related services provided by midstream companies, service companies or suppliers with whom we have a business relationship. We may not be able to recover through insurance some or any of the damages, losses or costs that may result from potential physical effects of climate change.

 

Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.

 

Hydraulic fracturing is an essential and common practice in the oil and natural gas industry used to stimulate production of natural gas and/or oil from dense subsurface rock formations. Hydraulic fracturing involves using water, sand and certain chemicals to fracture the hydrocarbon-bearing rock formation to allow flow of hydrocarbons into the wellbore. We expect to routinely apply hydraulic fracturing techniques in substantially all of our oil and natural gas drilling and completion programs. The process is typically regulated by state oil and natural gas commissions; however, the EPA has asserted federal regulatory authority over certain hydraulic fracturing activities using diesel under the Safe Drinking Water Act and in February 2014 released final guidance documents regarding the process for obtaining a permit for hydraulic fracturing involving diesel fuel pursuant to this regulatory authority.

 

Certain states, including Texas and Wyoming where we operate, have adopted, and other states are considering adopting, regulations that could impose more stringent permitting, public disclosure and well construction requirements on hydraulic fracturing operations or otherwise seek to ban fracturing activities

 

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altogether. In addition to state laws, local land use restrictions, such as city ordinances, may restrict or prohibit the performance of well drilling in general and/ or hydraulic fracturing in particular. In the event state, local or municipal legal restrictions are adopted in areas where we are currently conducting, or in the future plan to conduct operations, we may incur additional costs to comply with such requirements that may be significant in nature, experience delays or curtailment in the pursuit of exploration, development or production activities, and perhaps even be precluded from the drilling of wells.

 

There are also certain governmental reviews that have been conducted or are either underway or being proposed that focus on environmental aspects of hydraulic fracturing practices. The White House Council on Environmental Quality is coordinating an administration-wide review of hydraulic fracturing practices, and a committee of the United States House of Representatives has conducted an investigation of hydraulic fracturing practices. Furthermore, a number of federal agencies are analyzing, or have been requested to review, a variety of environmental issues associated with hydraulic fracturing. The EPA has commenced a study of the potential environmental effects of hydraulic fracturing on drinking water and groundwater. The EPA released a progress report on this study in late 2012 and expects to release a draft report in late 2014 for public comment and peer review. On May 19, 2014, EPA published in the Federal Register an Advanced Notice of Proposed Rulemaking under the Toxic Substances Control Act that seeks public comment on the types of information that should be reported or disclosed for hydraulic fracturing substances or mixtures and the mechanism for obtaining this information.

 

Moreover, EPA is developing pretreatment standards and effluent limitations for discharge of wastewater from hydraulic fracturing activities and plans to propose these standards for shale gas in 2014. Additionally, the U.S. Department of the Interior, Bureau of Land Management has re-proposed rules in May 2013 that would impose new requirements on hydraulic fracturing operations conducted on federal lands. The rule would require companies to publicly disclose the chemicals used in hydraulic fracturing operations after fracturing operations have been completed and includes provisions addressing well-bore integrity and flowback water management plans.

 

Further, on April 17, 2012, the EPA approved final rules that subject all oil and natural gas operations, including production, processing, transmission, storage and distribution activities to regulation under the New Source Performance Standards, or NSPS, and National Emission Standards for Hazardous Air Pollutants, or NESHAPS, programs. These rules also include NSPS standards for completions of hydraulically fractured gas wells. These standards include the reduced emission completion, or REC, techniques developed in EPA’s Natural Gas STAR program along with pit flaring of gas not sent to the gathering line. The REC standards are applicable to newly drilled and fractured wells as well as certain existing wells that are refractured. Further, the regulations under NESHAPS include maximum achievable control technology, or MACT, standards for those glycol dehydrators and storage vessels at major sources of hazardous air pollutants not currently subject to MACT standards. While these rules have been finalized, many of the rules’ provisions will be phased- in over time, with the more stringent requirements like REC not becoming effective until January 1, 2015.

 

Increased regulation and attention given to the hydraulic fracturing process could lead to greater opposition to, including litigation regarding, oil and natural gas production activities using hydraulic fracturing techniques. Additional legislation or regulation could also lead to operational delays or increased operating costs in the production of oil and natural gas, including from the developing shale plays, or could make it more difficult to perform hydraulic fracturing. The adoption of any federal, state or local laws or the implementation of regulations regarding hydraulic fracturing could potentially cause a decrease in the completion of new oil and natural gas wells, increased compliance costs and time, which could adversely affect our financial position, results of operations and cash flows.

 

Competition in the oil and natural gas industry is intense, making it more difficult for us to acquire properties, market oil and natural gas and secure trained personnel.

 

Our ability to acquire additional drilling locations and to find and develop reserves in the future will depend on our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive

 

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environment for acquiring properties, obtaining gathering, processing and pipeline transportation services, marketing oil and natural gas and securing equipment and trained personnel. Also, there is substantial competition for capital available for investment in the oil and natural gas industry. Many of our competitors possess and employ financial, technical and personnel resources substantially greater than ours. Those companies may be able to pay more for productive oil and natural gas properties and exploratory drilling locations or to identify, evaluate, bid for and purchase a greater number of properties and locations than our financial or personnel resources permit.

 

Furthermore, these companies may also be better able to withstand the financial pressures of unsuccessful drilling attempts, sustained periods of volatility in financial and commodity markets and generally adverse global and industry-wide economic conditions, and may be better able to absorb the burdens resulting from changes in relevant laws and regulations, which would adversely affect our competitive position. In addition, companies may be able to offer better compensation packages to attract and retain qualified personnel than we are able to offer. The cost to attract and retain qualified personnel in the regions in which we operate has increased over the past few years due to competition and may increase substantially in the future. We may not be able to compete successfully in the future in acquiring prospective reserves, developing reserves, marketing hydrocarbons, attracting and retaining quality personnel and raising additional capital, which could have a material adverse effect on our business.

 

The loss of senior management or technical personnel could adversely affect our operations.

 

To a large extent, we depend on the services of our senior management and technical personnel who have extensive experience and expertise in evaluating and analyzing producing oil and natural gas properties and drilling prospects, maximizing production from oil and natural gas properties, marketing oil and natural gas production, and developing and executing acquisition, financing and hedging strategies. Our ability to hire and retain senior management and technical personnel is important to our continued success and growth. The unexpected loss of the services of one or more of these individuals could negatively impact our ability to execute our business strategy. We do not maintain, nor do we plan to obtain, any insurance against the loss of any of these individuals.

 

Changes in the differential between benchmark prices of oil and natural gas and the reference or regional index price used to price our actual oil and natural gas sales could have a material adverse effect on our results of operations and financial condition.

 

The reference or regional index prices that we will use to price our oil and natural gas sales sometimes will reflect a discount to the relevant benchmark prices. The difference between the benchmark price and the price we reference in our sales contracts is called a differential. We cannot accurately predict oil and natural gas differentials. Changes in differentials between the benchmark price for oil and natural gas and the reference or regional index price we reference in our sales contracts could have a material adverse effect on our results of operations and financial condition.

 

Derivative activities could result in financial losses or could reduce our income.

 

To achieve more predictable cash flows and to reduce our exposure to adverse fluctuations in the prices of oil and natural gas, we have entered into and may in the future enter into additional derivative arrangements for a portion of our oil and natural gas production, including collars and fixed-price swaps. We may not designate our future derivative instruments as hedges for accounting purposes, in which case we would record all derivative instruments on our balance sheet at fair value. Changes in the fair value of derivative instruments are recognized in earnings. Accordingly, our earnings may fluctuate significantly as a result of changes in the fair value of our derivative instruments.

 

Derivative arrangements also expose us to the risk of financial loss in some circumstances, including when:

 

   

production is less than the volume covered by the derivative instruments;

 

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the counterparty to the derivative instrument defaults on its contract obligations; or

 

   

there is an increase in the differential between the underlying price in the derivative instrument and actual prices received.

 

In addition, our commodity derivative transactions will expose us to credit risk in the event of default by counterparties. Further deterioration in the credit markets may impact the credit ratings of our potential counterparties and affect their ability to fulfill their obligations to us and their willingness to enter into future transactions with us. A default under any of these agreements could negatively impact our financial performance.

 

The agreement governing our senior secured term loan requires that we enter into commodity derivative contracts for specified minimum and maximum percentages of our anticipated future production and impose additional restrictions on our commodity hedging activities. These restrictions could limit our flexibility in managing our exposure to commodity price risk. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Debt Facilities and Notes—Senior Secured Term Loan.”

 

The adoption of derivatives legislation by Congress, and implementation of that legislation by federal agencies, could have an adverse impact on our ability to mitigate risks associated with our business.

 

On July 21, 2010, the President signed into law the Dodd-Frank Wall Street Reform and Consumer Protection Act, or the Dodd-Frank Reform Act, which, among other provisions, establishes federal oversight and regulation of the over-the-counter derivatives market and entities that participate in that market. The legislation required the Commodities Futures Trading Commission, or the CFTC, and the SEC to promulgate rules and regulations implementing the new legislation, which they have done since late 2010 and continue to do into 2014. From late 2010 and continuing to the present date, the CFTC has proposed dozens of rules implementing the Dodd-Frank Reform Act, and has promulgated most of the required final rules based on those proposals. Due to these new rules, it is increasingly clear that the costs of derivatives-based hedging for commodities will likely increase for all market participants. Of particular concern, the Dodd-Frank Reform Act does not explicitly exempt end users from the requirements to post margin in connection with hedging activities. While several senators have indicated that it was not the intent of the Act to require margin from end users, the exemption is not in the Act. While rules proposed by the CFTC and federal banking regulators appear to allow for non-cash collateral and certain exemptions from margin for end users, the rules are not final and uncertainty remains. The full range of new Dodd-Frank requirements enacted, to the extent applicable to us or our derivatives counterparties, may result in increased costs and cash collateral requirements for the types of derivative instruments we use to mitigate and otherwise manage our financial and commercial risks related to fluctuations in natural gas, oil and NGL commodity prices. In addition, proposed rules that would impose federally-mandated position limits covering a wide range of derivatives positions, including non-exchange traded bilateral swaps related to commodities including oil and natural gas are being considered by the CFTC. If these position limits rules go into effect as proposed, they are likely to increase regulatory monitoring and compliance costs for all market participants, even where a given trading entity is not in danger of breaching position limits. These and other regulatory developments stemming from the Dodd-Frank Reform Act, including stringent new reporting requirements for derivatives positions and detailed criteria that must be satisfied to continue to enter into uncleared swap transactions, could have a material impact on our derivatives trading and hedging activities in the form of increased transaction costs and compliance responsibilities. Any of the foregoing consequences could have a material adverse effect on our financial position, results of operations and cash flows.

 

Declining general economic, business or industry conditions could have a material adverse effect on our results of operations.

 

Concerns over the worldwide economic outlook, geopolitical issues, the availability and cost of credit and the United States mortgage and real estate markets contributed to increased volatility and diminished expectations for the global economy. These factors, combined with volatile commodity prices, declining business

 

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and consumer confidence and increased unemployment resulted in a worldwide recession during the second half of 2008 and 2009. Concerns about global economic growth could have a significant adverse effect on global financial markets and commodity prices. If the economic climate in the United States or abroad were to deteriorate, demand for petroleum products could diminish, which could depress the prices at which we could sell our oil and natural gas and ultimately decrease our revenue and profitability.

 

Increased costs of capital could adversely affect our business.

 

Our business and operating results can be harmed by factors such as the availability, terms and cost of capital, increases in interest rates or a reduction in credit rating. Changes in any one or more of these factors could cause our cost of doing business to increase, limit our access to capital, limit our ability to pursue acquisition opportunities, reduce our cash flows available for drilling and place us at a competitive disadvantage. Recent and continuing disruptions and volatility in the global financial markets may lead to an increase in interest rates or a contraction in credit availability impacting our ability to finance our operations. We require continued access to capital. A significant reduction in the availability of credit could materially and adversely affect our ability to achieve our planned growth and operating results.

 

We may be subject to risks in connection with acquisitions, including the Ft. Trinidad acquisition, and the integration of significant acquisitions may be difficult.

 

We regularly evaluate acquisitions of reserves, properties, prospects and leaseholds and other strategic transactions that appear to fit within our overall business strategy. The successful acquisition of properties routinely requires an assessment of multiple factors, including:

 

   

recoverable reserves;

 

   

future oil and natural gas prices and their appropriate differentials;

 

   

development and operating costs; and

 

   

potential environmental and other liabilities.

 

The accuracy of these assessments is inherently uncertain. In connection with these assessments, we will perform a review of the subject properties that we believe to be generally consistent with industry practices. Our review will not reveal all existing or potential problems nor will it permit us to become sufficiently familiar with the properties to fully assess their deficiencies and potential recoverable reserves. Inspections may not always be performed on every well, and environmental problems are not necessarily observable even when an inspection is undertaken. Even when problems are identified, the seller may be unwilling or unable to provide effective contractual protection against all or part of the problems. We often do not hold rights to contractual indemnification for environmental liabilities and acquire properties on an “as is” basis. Although the purchase and sale agreement for the Ft. Trinidad acquisition includes certain representations and warranties of the sellers and requires the sellers to indemnify us for certain losses, these representations, warranties and indemnities are subject to significant limitations and may not protect us against all liabilities or other problems associated with the acquired properties.

 

Significant acquisitions and other strategic transactions may involve other risks, including:

 

   

diversion of our management’s attention to evaluating, negotiating and integrating significant acquisitions and strategic transactions;

 

   

challenge and cost of integrating acquired operations, information management and other technology systems and business cultures with those of ours while carrying on our ongoing business;

 

   

difficulty associated with coordinating geographically separate organizations; and

 

   

challenge of attracting and retaining personnel associated with acquired operations.

 

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The process of integrating operations could cause an interruption of, or loss of momentum in, the activities of our business. Members of our senior management may be required to devote considerable amounts of time to this integration process, which will decrease the time they will have to manage our business. If our senior management is not able to effectively manage the integration process, or if any significant business activities are interrupted as a result of the integration process, our business could suffer.

 

Additionally, the success of a significant acquisition will depend, in part, on our ability to realize anticipated growth opportunities from combining the acquired assets or operations into our existing operations. Even if a combination is successful, it may not be possible to realize the full benefits we may expect in estimated proved reserves, production volume, cost savings from operating synergies or other benefits anticipated from an acquisition or realize these benefits within the expected time frame. Anticipated benefits of an acquisition may be offset by operating losses relating to changes in commodity prices, or in oil and natural gas industry conditions, or by risks and uncertainties relating to the exploratory prospects of the combined assets or operations, or an increase in operating or other costs or other difficulties. If we fail to realize the benefits we anticipate from an acquisition, our results of operations may be adversely affected.

 

Because of the size of the Ft. Trinidad acquisition relative to our previously existing operations, the foregoing risks related to acquisitions are magnified in connection with the Ft. Trinidad acquisition. The Ft. Trinidad acquisition substantially expanded the scope of our operations. Our failure to successfully adapt to the expanded scope of operations, integrate the acquired assets or realize the anticipated benefits of the Ft. Trinidad acquisition would have a material adverse effect on our business, financial condition and results of operations.

 

We may incur losses as a result of title defects in the properties in which we invest.

 

It is our practice in acquiring oil and natural gas leases or interests not to incur the expense of retaining lawyers to examine the title to the mineral interest. Rather, we rely upon the judgment of oil and natural gas lease brokers or landmen who perform the fieldwork in examining records in the appropriate governmental office before attempting to acquire a lease in a specific mineral interest.

 

Prior to the drilling of an oil or gas well, however, it is the normal practice in our industry for the person or company acting as the operator of the well to obtain a preliminary title review to ensure there are no obvious defects in title to the well. Frequently, as a result of such examinations, certain curative work must be done to correct defects in the marketability of the title, and such curative work entails expense. Our failure to cure any title defects may delay or prevent us from utilizing the associated mineral interest, which may adversely impact our ability in the future to increase production and reserves. Additionally, undeveloped acreage has greater risk of title defects than developed acreage, and a majority of our acreage is undeveloped. If there are any title defects or defects in assignment of leasehold rights in properties in which we hold an interest or that we acquire, we will suffer a financial loss.

 

Certain federal income tax deductions currently available with respect to natural gas and oil exploration and development may be eliminated, and additional state taxes on natural gas extraction may be imposed, as a result of future legislation.

 

The Obama Administration’s budget proposal for fiscal year 2015 and legislation introduced in a prior session of Congress include proposals that would, if enacted, make significant changes to U.S. federal income tax laws, including the elimination of certain key U.S. federal income tax incentives currently available to oil and natural gas exploration and production companies. These changes include, but are not limited to, (1) the repeal of the percentage depletion allowance for oil and natural gas properties, (2) the elimination of current deductions for intangible drilling and development costs, (3) the elimination of the deduction for certain domestic production activities, and (4) an extension of the amortization period for certain geological and geophysical expenditures. It is unclear whether these or similar changes will be enacted and, if enacted, how soon any such changes could become effective.

 

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The passage of any legislation as a result of these proposals or any other similar change in U.S. federal income tax law could eliminate or postpone certain tax deductions that are currently available with respect to oil and natural gas exploration and development, and any such change, as well as any changes to or the imposition of new state or local taxes (including the imposition of, or increase in, production, severance or similar taxes), could negatively affect our financial condition and results of operations.

 

Risks Related to This Offering and our Common Stock

 

The initial public offering price of our common stock may not be indicative of the market price of our common stock after this offering. In addition, an active liquid trading market for our common stock may not develop and our stock price may be volatile.

 

Prior to this offering, our common stock was not traded on any market. An active and liquid trading market for our common stock may not develop or be maintained after this offering. Liquid and active trading markets usually result in less price volatility and more efficiency in carrying out investors’ purchase and sale orders. The market price of our common stock could vary significantly as a result of a number of factors, some of which are beyond our control. In the event of a decline in the market price of our common stock, you could lose a substantial part or all of your investment in our common stock. The initial public offering price will be negotiated between us and representatives of the underwriters, based on the numerous factors which we discuss in the “Underwriting” section of this prospectus, and may not be indicative of the market price of our common stock after this offering. Consequently, you may not be able to sell shares of our common stock at prices equal to or greater than the price paid by you in the offering.

 

Additionally, the stock markets have experienced significant price and volume fluctuations. As a result, following this offering, the market price of our common stock may be volatile and may decline, including for reasons unrelated to our operating performance or prospects. The market price of our common stock could be subject to significant fluctuations in response to various factors or events, including among other things:

 

   

our operating performance and the performance of other similar companies;

 

   

actual or anticipated differences in our operating results;

 

   

changes in our revenue or earnings estimates, if any, or recommendations by securities analysts;

 

   

publication of research reports about us or our industry by securities analysts;

 

   

additions and departures of key personnel;

 

   

strategic decisions by us or our competitors, such as acquisitions, divestments, spin-offs, joint ventures, strategic investments or changes in business strategy;

 

   

the passage of legislation or other regulatory developments that adversely affect us or our industry;

 

   

speculation in the press or investment community;

 

   

sales of our common stock by us or our stockholders, or the perception that such sales may occur;

 

   

actions by institutional stockholders;

 

   

changes in accounting principles;

 

   

terrorist acts; and

 

   

general market conditions, including fluctuations in commodity prices or factors unrelated to our performance.

 

These factors may lower the trading price of our common stock, regardless of our actual operating performance. In addition, the stock markets, from time to time, experience extreme price and volume fluctuations that may be unrelated or disproportionate to the operating performance of companies. These broad fluctuations may lower the market price of our common stock.

 

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Certain of our directors, executive officers and other members of management, and certain of our large stockholders have direct economic interests in some of our properties, and their interests may not be aligned with our interests.

 

Certain of our stockholders, directors, executive officers and other members of our management have overriding royalty interests relating to our existing oil and natural gas properties. These overriding royalty interests generally entitle them to percentages of the net revenue associated with sales of oil and natural gas produced from these oil and natural gas properties, without any corresponding responsibility for payment of any expenses other than certain taxes. These percentages range from 0% to 2.5% in the East Texas stacked play, 0% to 2.2% in the Permian Basin and 0% to 4.2% in the DJ Basin. Because the amounts of the overriding royalty interest percentages vary among our properties and do not apply to all of our properties, including properties acquired in the Chesapeake acquisition and the Ft. Trinidad acquisition, and will not apply to other properties acquired after completion of this offering, the overriding royalty interests may create conflicts of interest for our management in setting our exploration and development priorities. Since October 2012, we have not granted, and we do not intend to grant, additional overriding royalty interests with respect to our properties to our directors, executive officers or other employees.

 

The concentration of our capital stock ownership by our largest stockholders will limit your ability to influence corporate matters.

 

Upon completion of this offering, we anticipate that Hunt Pettit, our founder, President and Chief Executive Officer, will own approximately     % of our outstanding common stock and affiliates of Highbridge Principal Strategies, LLC, or Highbridge, will own approximately     % of our outstanding common stock. Consequently, Mr. Pettit and Highbridge will continue to have substantial control over all matters that require approval by our stockholders, including the election of directors and approval of significant corporate transactions. Additionally, Mr. Pettit and Highbridge are entitled to nominate persons to serve on our Board of Directors, subject to their maintaining certain levels of ownership of our common stock. See “Management—Board of Directors.” Mr. Pettit and Highbridge may have interests that are different from other stockholders or holders of notes, and they could delay or prevent an acquisition or merger of our company even if the transaction could benefit our stockholders. Moreover, this concentration of our capital stock ownership and control makes it very difficult for other stockholders to replace directors and management without the consent of the controlling stockholders. In addition, this significant concentration of capital stock ownership may adversely affect the price prospective buyers are willing to pay for our common stock because investors often perceive disadvantages in owning stock in companies with controlling stockholders, which could, in turn, materially and adversely affect the trading price of our common stock.

 

Purchasers of common stock in this offering will experience immediate and substantial dilution of $         per share.

 

Based on an assumed initial public offering price of $         per share, purchasers of our common stock in this offering will experience an immediate and substantial dilution of $         per share in the pro forma net tangible book value per share of our common stock from the initial public offering price, and our pro forma net tangible book value as of June 30, 2014 after giving effect to this offering would be $         per share. See “Dilution” for a complete description of the calculation of pro forma net tangible book value.

 

Because we are a relatively small company, the requirements of being a public company, including compliance with the reporting requirements of the Exchange Act and the requirements of the Sarbanes-Oxley Act, may strain our resources, increase our costs and distract management; and we may be unable to comply with these requirements in a timely or cost-effective manner.

 

As a public company with listed equity securities, we will need to comply with certain laws, regulations and requirements, including corporate governance provisions of the Sarbanes-Oxley Act of 2002, related regulations of the SEC and the requirements of the New York Stock Exchange, or the NYSE, with which we are not required

 

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to comply as a private company. Complying with these statutes, regulations and requirements will occupy a significant amount of time of our board of directors and management and will significantly increase our costs and expenses. We will need to:

 

   

institute a more comprehensive compliance function;

 

   

design, establish, evaluate and maintain a system of internal control over financial reporting in compliance with the requirements of Section 404 of the Sarbanes-Oxley Act of 2002 and the related rules and regulations of the SEC and the Public Company Accounting Oversight Board;

 

   

comply with rules promulgated by the NYSE;

 

   

prepare and distribute periodic public reports in compliance with our obligations under the federal securities laws;

 

   

establish new internal policies, such as those relating to disclosure controls and procedures and insider trading;

 

   

involve and retain to a greater degree outside counsel and accountants in the above activities; and

 

   

establish an investor relations function.

 

However, for as long as we remain an “emerging growth company” as defined in the JOBS Act, we may take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies. See “Summary—Implications of Being an Emerging Growth Company.” If we choose to take advantage of some or all of these reduced reporting requirements, the information that we provide to our stockholders may be different from information provided by other public companies.

 

While we believe our internal control over financial reporting has been effective at supporting our past financial reporting needs, it may not continue to be effective at reporting activities as a public company operating under our current business strategy. If one or more material weaknesses emerge related to reporting the activities related to our current business strategy, or if we otherwise fail to establish and maintain effective internal control over financial reporting, our ability to accurately report our financial results could be adversely affected.

 

Prior to completion of this offering, we have been a private company with limited accounting personnel to adequately execute our accounting processes and other supervisory resources with which to address our internal control over financial reporting. While we believe our internal control over financial reporting was effective under our business strategy of acquiring and selling undeveloped leasehold acreage, in the first quarter of 2012, we adopted a business strategy to develop and exploit our undeveloped leasehold acreage. We have implemented plans to enhance our financial reporting activities related to our current strategy and to meet the financial reporting requirements required of a public company. However, there is no certainty that as a result of our actions we will be able to maintain effective internal control over financial reporting.

 

Our independent registered public accounting firm is not required to formally attest to the effectiveness of our internal control over financial reporting under Section 404 of the Sarbanes-Oxley Act until the later of the year following our first annual report required to be filed with the SEC or the date we are no longer an emerging growth company. At such time, our independent registered public accounting firm may issue a report that is adverse in the event it is not satisfied with the level at which our controls are documented, designed or operating.

 

Effective internal controls are necessary for us to provide reliable financial reports, prevent fraud and operate successfully as a public company. If we cannot provide reliable financial reports or prevent fraud, our ability to accurately report our financial results could be adversely affected and our reputation and operating results would be harmed. We cannot be certain that our efforts to develop and maintain our internal controls will be successful, that we will be able to maintain adequate controls over our financial processes and reporting in the

 

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future or that we will be able to comply with our obligations under Section 404 of the Sarbanes-Oxley Act. Any failure to develop or maintain effective internal controls, or difficulties encountered in implementing or improving our internal controls, could harm our operating results or cause us to fail to meet our reporting obligations. Ineffective internal controls could also cause investors to lose confidence in our reported financial information, which would likely have a negative effect on the trading price of our shares of common stock.

 

We are an “emerging growth company,” and we cannot be certain whether the reduced disclosure requirements applicable to emerging growth companies will make our common stock less attractive to investors.

 

We are an “emerging growth company,” as defined in the JOBS Act, and we may take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies. See “Summary—Implications of Being an Emerging Growth Company.” We cannot predict whether investors will find our common stock less attractive because we may rely on these exemptions. If some investors find our common stock less attractive as a result, there may be a less active trading market for our common stock and our stock price may be more volatile.

 

In addition, Section 107 of the JOBS Act provides that an emerging growth company may take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. In other words, an emerging growth company may delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. However, we are choosing to “opt out” of such extended transition period, and as a result, we will comply with new or revised accounting standards on the relevant dates on which adoption of such standards is required for non-emerging growth companies. Section 107 of the JOBS Act provides that our decision to opt out of the extended transition period for complying with new or revised accounting standards is irrevocable.

 

We do not intend to pay dividends on our common stock and, consequently, your only opportunity to achieve a return on your investment is if the price of our stock appreciates.

 

We do not plan to declare dividends on shares of our common stock in the foreseeable future. Additionally, the agreement governing the senior secured term loan places certain restrictions on our ability to pay cash dividends. Consequently, your only opportunity to achieve a return on your investment in us will be if the market price of our common stock appreciates, which may not occur, and you sell your shares at a profit. There is no guarantee that the price of our common stock that will prevail in the market after this offering will ever exceed the price that you pay.

 

We may invest or spend our net proceeds from this offering in ways with which you may not agree or in ways that may not yield a return.

 

A portion of the net proceeds from this offering is expected to be used for our capital expenditure budget. Our management will have considerable discretion in the application of our net proceeds, and you will not have the opportunity, as part of your investment decision, to assess whether the proceeds are being used appropriately. Until our net proceeds are used, they may be placed in investments that do not produce significant income or that may lose value.

 

Future sales of our common stock in the public market could lower our stock price, and any additional capital raised by us through the sale of equity or convertible securities will dilute your ownership in us.

 

We may sell additional shares of common stock in subsequent public offerings or otherwise issue additional shares of common stock or convertible securities. Assuming the underwriters do not exercise their option to purchase additional shares and giving effect to the conversion of all outstanding convertible notes and the exercise of outstanding warrants based on an assumed initial public offering price of $         per share, after the completion of this offering, we will have              outstanding shares of common stock. Following the completion

 

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of this offering, our existing stockholders (including holders of convertible notes and warrants) will beneficially own              shares, or     % of our total outstanding shares, all of which will be restricted from immediate resale under the federal securities laws and              shares of which will be subject to lock-up agreements described in “Underwriting,” but may be sold into the market in the future. Our existing stockholders and warrant holders (excluding holders of convertible notes) are parties to a registration rights agreement with us that will require us to effect the registration of their shares in certain circumstances no earlier than 180 days after the date of this prospectus. In addition, we are required to file a shelf registration statement that must be effective within 180 days after the closing of this this offering covering the resale of all shares of our common stock that are issued upon conversion of the convertible notes, other than the shares being sold in this offering.

 

As soon as practicable after this offering, we intend to file a registration statement with the SEC on Form S-8 providing for the registration of              shares of our common stock reserved for issuance under our stock incentive plan. Subject to the satisfaction of vesting conditions, restrictions applicable to our affiliates under Rule 144 under the Securities Act and the expiration of lock-up agreements, shares registered under our registration statement on Form S-8 will be available for resale immediately in the public market without restriction.

 

We cannot predict the size of future issuances of our common stock or the effect, if any, that future issuances and sales of shares of our common stock will have on the market price of our common stock. Sales of substantial amounts of our common stock (including shares issued in connection with an acquisition), or the perception that such sales could occur, may adversely affect prevailing market prices of our common stock.

 

Our amended and restated certificate of incorporation and amended and restated bylaws and Delaware law contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our common stock.

 

Our amended and restated certificate of incorporation authorizes our board of directors to issue preferred stock without stockholder approval. If our board of directors elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our amended and restated certificate of incorporation and amended and restated bylaws could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to and desirable by our stockholders, including:

 

   

a classified board of directors, so that only approximately one-third of our directors are elected each year;

 

   

limitations on the removal of directors;

 

   

limitations on the ability of our stockholders to call special meetings; and

 

   

advance notice provisions for stockholder proposals and nominations for elections to the board of directors to be acted upon at meetings of stockholders.

 

Furthermore, because we are incorporated in Delaware, we are governed by the provisions of Section 203 of the General Corporation Law of the State of Delaware, which prohibits, with some exceptions, stockholders owning in excess of 15% of our outstanding voting stock from engaging in business combination transactions with us. See “Description of Capital Stock—Anti-Takeover Effects of Provisions of Our Certificate of Incorporation, Our Bylaws and Delaware Law.”

 

We may issue preferred stock, the terms of which could adversely affect the voting power or value of our common stock.

 

Our amended and restated certificate of incorporation authorizes us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designations, preferences, limitations and relative rights, including preferences over our common stock respecting dividends and distributions, as our board of directors may determine. The terms of one or more classes or series of preferred stock could adversely impact the voting power or value of our common stock. For example, we might grant holders of preferred stock

 

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the right to elect some number of our directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we might assign to holders of preferred stock could affect the residual value of our common stock.

 

Our amended and restated certificate of incorporation will designate the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our stockholders, which could limit our stockholders’ ability to obtain a favorable judicial forum for disputes with us or our directors, officers, employees or agents.

 

Our amended and restated certificate of incorporation will provide that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware will, to the fullest extent permitted by applicable law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees or agents to us or our stockholders, (iii) any action asserting a claim against us or any director or officer or other employee of ours arising pursuant to any provision of the General Corporation Law of the State of Delaware, our amended and restated certificate of incorporation or our bylaws, or (iv) any action asserting a claim against us or any director or officer or other employee of ours that is governed by the internal affairs doctrine, in each such case subject to such Court of Chancery having personal jurisdiction over the indispensable parties named as defendants therein. Any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock will be deemed to have notice of, and consented to, the provisions of our amended and restated certificate of incorporation described in the preceding sentence. This choice of forum provision may limit a stockholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our amended and restated certificate of incorporation inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, financial condition or results of operations.

 

The underwriters of this offering may waive or release parties to the lock-up agreements entered into in connection with this offering, which could adversely affect the price of our common stock.

 

We, each of our executive officers and directors and certain of our existing stockholders (including the selling stockholders) have entered into lock-up agreements with respect to their common stock, pursuant to which they are subject to certain resale restrictions for a period of 180 days following the effectiveness date of the registration statement of which this prospectus forms a part. The representative of the underwriters, at any time and without notice, may release all or any portion of the common stock subject to the foregoing lock-up agreements. If the restrictions under the lock-up agreements are waived, then common stock will be available for sale into the public markets, which could cause the market price of our common stock to decline and impair our ability to raise capital.

 

If securities or industry analysts do not publish research or reports about our business, if they adversely change their recommendations regarding our common stock or if our operating results do not meet their expectations, our stock price could decline.

 

The trading market for our common stock will be influenced by the research and reports that industry or securities analysts publish about us or our business. If one or more of these analysts cease coverage of our company or fail to publish reports on us regularly, we could lose visibility in the financial markets, which in turn could cause our stock price or trading volume to decline. Moreover, if one or more of the analysts who cover our company downgrades our common stock or if our operating results do not meet their expectations, our stock price could decline.

 

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

 

This prospectus contains forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our control. All statements, other than statements of historical fact included in this prospectus, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this prospectus, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words.

 

Forward-looking statements may include statements about our:

 

   

discovery and development of oil and natural gas reserves;

 

   

cash flows and liquidity;

 

   

business and financial strategy, budget, projections and operating results;

 

   

oil and natural gas realized prices;

 

   

timing and amount of future production of oil and natural gas;

 

   

availability of drilling and production equipment;

 

   

availability of oil field labor;

 

   

amount, nature and timing of capital expenditures, including future development costs;

 

   

borrowing capacity under future credit facilities;

 

   

availability and terms of capital;

 

   

drilling and completion of wells;

 

   

competition;

 

   

marketing of oil and natural gas;

 

   

timing, location and size of property acquisitions;

 

   

expected benefits of the Ft. Trinidad acquisition;

 

   

costs of exploiting and developing our properties and conducting other operations;

 

   

general economic and business conditions;

 

   

effectiveness of our risk management activities;

 

   

environmental and other liabilities;

 

   

counterparty credit risk;

 

   

governmental regulation and taxation of the oil and natural gas industry; and

 

   

plans, objectives, expectations and intentions contained in this prospectus that are not historical.

 

All forward-looking statements speak only as of the date of this prospectus. You should not place undue reliance on these forward-looking statements. Although we believe that our plans, objectives, expectations and intentions reflected in or suggested by the forward-looking statements we make in this prospectus are reasonable,

 

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we can give no assurance that these plans, objectives, expectations or intentions will be achieved. We disclose important factors that could cause our actual results to differ materially from our expectations under “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and elsewhere in this prospectus. These factors include risks related to:

 

   

variations in the market demand for, and prices of, oil and natural gas;

 

   

estimates of oil and natural gas data;

 

   

the adequacy of our capital resources and liquidity;

 

   

general economic and business conditions;

 

   

the Ft. Trinidad acquisition;

 

   

failure to realize expected value creation from property acquisitions;

 

   

uncertainties about our ability to replace reserves and economically develop our reserves;

 

   

risks related to the concentration of our operations;

 

   

drilling results;

 

   

potential financial losses or earnings reductions from our commodity price risk management programs;

 

   

potential adoption of new governmental regulations; and

 

   

our ability to satisfy future cash obligations and environmental costs.

 

These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.

 

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USE OF PROCEEDS

 

We expect to receive net proceeds of approximately $         million from the sale of our common stock, assuming an initial public offering price of $         per share (the midpoint of the price range set forth on the cover page of this prospectus) and after deducting estimated expenses payable by us and underwriting discounts and commissions. An increase or decrease in the initial public offering price of $1.00 per share of common stock would cause the net proceeds that we will receive from this offering, after deducting estimated expenses payable by us and underwriting discounts and commissions, to increase or decrease by approximately $         million. We will not receive any of the proceeds from the sale of shares of our common stock by the selling stockholders. We will pay all expenses related to this offering, other than the underwriting discount related to the shares sold by the selling stockholders.

 

We intend to use a portion of the net proceeds we receive from this offering to repay in full the Chesapeake note, which had an outstanding principal amount of approximately $20.3 million as of June 30, 2014. We intend to use the remainder of the net proceeds from this offering to fund a portion of our capital expenditure budget of $430 million for the period from July 1, 2014 through December 31, 2015. The capital expenditure budget includes approximately $111 million for the period from July 1, 2014 through December 31, 2014 and approximately $244 million in 2015 for drilling and developing our leasehold acreage and approximately $27 million for the period from July 1, 2014 through December 31, 2014 and approximately $48 million in 2015 for other capital expenditures, including acquiring additional oil and natural gas leases, extending the expiration of our current leasehold acreage and acquiring 3D seismic data. We intend to fund the remainder of our capital expenditure budget with cash on hand and cash flows from operations.

 

The following table sets forth the expected sources and uses of funds for repayment of the Chesapeake note and our capital expenditure budget from July 1, 2014 through December 31, 2015.

 

Sources of Funds ($ in millions)

         

Uses of Funds ($ in millions)

      

Net proceeds from this offering

   $        

Repayment of Chesapeake note and interest(4)

   $ 20   

Current cash and cash equivalents(1)

     132      

Remaining 2014 drilling and completion capital

     111   

Other potential sources(2)

     

2015 drilling and completion capital

     244   
     

Remaining other 2014 capital(5)

     27   
     

Other 2015 capital(5)

     48   
  

 

 

       

 

 

 

Total sources of funds(3)

   $ 450      

Total uses of funds(3)

   $ 450   
  

 

 

       

 

 

 

 

(1)   As of June 30, 2014, pro forma for the Pro Forma Transactions described under “Prospectus Summary—Summary Historical and Pro Forma Consolidated Financial Statements.”
(2)   Other potential sources include cash flow from operations, proceeds from potential asset divestitures and/or future equity or debt financings.
(3)   Certain totals may not add due to rounding.
(4)   $20.3 million principal amount as of June 30, 2014.
(5)   Includes land acquisition, leasehold extension, seismic surveys and other capital.

 

The ultimate amount of capital we will expend is largely discretionary and may fluctuate materially based on market conditions, the success of drilling operations, access to capital and other factors. Additionally, the timing and costs of drilling on our non-operated leasehold acreage in the East Texas stacked play generally will be within the control of the operator of the acreage.

 

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DIVIDEND POLICY

 

We do not anticipate declaring or paying any cash dividends to holders of our common stock in the foreseeable future. We currently intend to retain future earnings, if any, to finance the expansion of our business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors, including our results of operations, financial condition, capital requirements and investment opportunities. In addition, the agreement governing our senior secured term loan restricts our ability to pay cash distributions.

 

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CAPITALIZATION

 

The following table sets forth our capitalization as of June 30, 2014:

 

   

on a historical basis;

 

   

on a pro forma basis giving effect to the Pro Forma Transactions described under “Prospectus Summary—Summary and Pro Forma Consolidated Financial Data” other than the conversion of convertible notes and warrants described below; and

 

   

on a pro forma as adjusted basis giving further effect to (1) this offering and the receipt of the net proceeds therefrom, (2) the use of a portion of the net proceeds to repay the Chesapeake note, (3) the conversion of all convertible notes into shares of our common stock assuming an initial public offering price of $         per share, and (4) the automatic exercise of outstanding warrants for shares of our common stock at the completion of this offering on a net basis assuming an initial public offering price of $         per share.

 

You should read the following table in conjunction with “Use of Proceeds,” “Selected Consolidated Financial Data,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our historical consolidated financial statements and related notes thereto appearing elsewhere in this prospectus.

 

     As of June 30, 2014  
     Historical     Pro Forma     Pro Forma
As Adjusted
 
     (in thousands)  

Cash, cash equivalents and deposits

   $ 2,706       131,520      $     
  

 

 

   

 

 

   

 

 

 

Long-term debt, including current maturities:

      

Senior unsecured notes

     225,000 (1)     —          —    

Senior secured term loan

     —         775,000 (2)      775,000 (2)

Convertible notes

     —         375,000 (3)     —     

Chesapeake note

     20,302        20,302        —     
  

 

 

   

 

 

   

 

 

 

Total long-term debt, including current maturities

     245,302        1,170,302        775,000   
  

 

 

   

 

 

   

 

 

 

Stockholders’ equity:

      

Preferred stock, $0.01 par value;              shares authorized,             no shares issued and outstanding

     —         —         —    

Common stock, $0.01 par value;              shares authorized,              shares (Historical and Pro Forma) and              shares (Pro Forma As Adjusted) issued and outstanding

     5       5     

Additional paid-in capital

     47,334       

Accumulated deficit

     (15,651 )    
  

 

 

   

 

 

   

 

 

 

Total stockholders’ equity

     31,688       307,667     
  

 

 

   

 

 

   

 

 

 

Total capitalization

   $ 276,990     $ 1,140,402      $     
  

 

 

   

 

 

   

 

 

 

 

(1)   Excludes discount of approximately $20.3 million.
(2)   Excludes estimated discount of approximately $11.6 million.
(3)   Excludes estimated discount of approximately $74.7 million related to the fair value of embedded derivatives related to the conversion and change of control features of the notes. See the notes to the unaudited pro forma combined and consolidated financial statements included elsewhere in this prospectus.

 

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DILUTION

 

Purchasers of our common stock in this offering will experience immediate and substantial dilution in the net tangible book value per share of the common stock for accounting purposes. Our net tangible book value as of June 30, 2014, after giving pro forma effect to the Pro Forma Transactions described under “Prospectus Summary—Summary Historical and Pro Forma Consolidated Financial Statements,” was approximately $         million, or $         per share of common stock. Pro forma net tangible book value per share is determined by dividing our pro forma tangible net worth (tangible assets less total liabilities) by the total number of outstanding shares of common stock outstanding immediately prior to the closing of this offering, after giving effect to the conversion of all convertible notes and the automatic conversion of outstanding warrants at the completion of this offering. After giving further effect to the sale of the shares in this offering and assuming the receipt of the estimated net proceeds (after deducting estimated discounts and expenses of this offering), our adjusted pro forma net tangible book value as of June 30, 2014 would have been approximately $         million, or $         per share. This represents an immediate increase in the net tangible book value of $         per share to our existing stockholders and an immediate dilution (i.e., the difference between the offering price and the adjusted pro forma net tangible book value after this offering) to new investors purchasing shares in this offering of $         per share. The following table illustrates the per share dilution to new investors purchasing shares in this offering:

 

Assumed initial public offering price per share

   $            

Pro forma net tangible book value per share as of June 30, 2014

   $            

Increase per share attributable to new investors in this offering

   $     
  

 

 

 

As adjusted pro forma net tangible book value per share after giving effect to this offering

  
  

 

 

 

Dilution in pro forma net tangible book value per share to new investors in this offering

   $            
  

 

 

 

 

The following table summarizes, on an as adjusted pro forma basis as of June 30, 2014, the total number of shares of common stock owned by existing stockholders and to be owned by new investors, the total consideration paid, and the average price per share paid by our existing stockholders and to be paid by new investors in this offering at $        , which is the midpoint of the range of the initial public offering prices set forth on the cover page of this prospectus, calculated before deduction of estimated underwriting discounts and commissions:

 

     Shares Acquired(1)     Total Consideration     Average
Price
Per Share
 
     

Number

   Percent     Amount      Percent    

Existing stockholders

               $                             $                

New investors

                          
  

 

  

 

 

   

 

 

    

 

 

   

 

 

 

Total

        100.0   $           100.0   $     
  

 

  

 

 

   

 

 

    

 

 

   

 

 

 

 

(1)   The number of shares disclosed for the existing stockholders includes (i)              shares being sold by the selling stockholders, (ii)              shares to be issued upon automatic conversion of outstanding warrants at the completion of this offering on a net basis assuming an initial public offering price of $         per share and (iii)              shares to be issued upon conversion of the outstanding convertible notes assuming an initial public offering price of $         per share. The number of shares disclosed for the new investors does not include the              shares being purchased by the new investors from the selling stockholders in this offering.

 

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SELECTED CONSOLIDATED FINANCIAL DATA

 

Set forth below are our selected consolidated financial data as of the dates and for the periods indicated. The selected historical consolidated financial data as of December 31, 2013 and 2012 and for the years ended December 31, 2013, 2012 and 2011, are derived from our audited consolidated financial statements included elsewhere in this prospectus. The selected historical consolidated balance sheet data as of December 31, 2011 are derived from our audited consolidated financial statements not included in this prospectus. The selected historical condensed consolidated financial data as of June 30, 2014 and for the six months ended June 30, 2014 and 2013 are derived from our condensed unaudited consolidated financial statements included elsewhere in this prospectus, which, in the opinion of our management, include all adjustments, consisting only of normal recurring adjustments, necessary for a fair statement of this information. Results of operations for the six months ended June 30, 2014 and 2013 are not necessarily indicative of the results of operations for the entire year or any future period.

 

The information set forth below should be read together with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the historical financial statements and the notes thereto included elsewhere in this prospectus. The financial data included in this prospectus may not be indicative of our future results of operations, financial position and cash flows.

 

     Year Ended
December 31,
    Six Months Ended
June 30,
 
     2011     2012     2013     2013     2014  
                       (unaudited)  

Statement of operations data:

          

Revenues

   $ —        $ 216      $ 16,437      $ 1,942      $ 21,248   

Operating expenses

     1,777        14,989        36,333        18,795        23,777   

Income (loss) from operations

     (1,777     (14,773     (19,896     (16,853     (2,529

Net income (loss)

     (1,478     8,734        (21,767     (9,432     (3,282

 

     As of December 31,      As of June 30,  
             2011                      2012                     2013              2014  
                         (unaudited)  

Balance sheet data:

          

Cash and cash equivalents

   $ 5,397       $ 10,228      $ 3,569       $ 2,706   

Property, plant and equipment

     21,641         33,448        229,257         280,503   

Total assets

     27,968         68,074        243,573         296,473   

Long-term debt, net of discount

     9,928         14,191 (1)      168,336         224,985   

Total equity

     14,936         28,564        30,265         31,688   

 

(1)   Excludes $7.1 million reflected as current note payable

 

     Year Ended
December 31,
    Six Months Ended
June 30,
 
     2011     2012     2013     2013     2014  
                       (unaudited)  
     (in thousands)  

Other financial data:

          

Net cash provided by (used in) operating activities

   $ (1,004   $ (11,072   $ 19,946      $ (596   $ (13,747

Net cash provided by (used in) investing activities

     (17,868     12,911        (164,482     (70,687     (41,912

Net cash provided by financing activities

     21,704        2,992        137,877        116,095        54,796   

Opening cash

     2,565        5,397        10,228        10,228        3,569   

Closing cash

     5,397        10,228        3,569        55,040        2,706   

 

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our combined financial statements and related notes appearing elsewhere in this prospectus. The following discussion contains “forward-looking statements” that reflect our future plans, estimates, beliefs and expected performance. We caution that assumptions, expectations, projections, intentions, or beliefs about future events may, and often do, vary from actual results and the differences can be material. See “Risk Factors” and “Cautionary Note Regarding Forward-Looking Statements.”

 

Overview

 

We are an independent exploration and production company focused on the acquisition, exploration, development and exploitation of conventional and unconventional oil and natural gas resources. As of July 31, 2014 we owned approximately 92,828 net acres in three basins: the East Texas Basin where we are pursuing opportunities in the Lower Cretaceous formations of the Buda, Georgetown, Edwards and Glen Rose (the Buda-Rose play), the Woodbine sandstone and the Eagle Ford shale, which we refer to collectively as the East Texas stacked play; the Permian Basin in West Texas; and the Denver-Julesburg Basin in Wyoming, which we refer to as the DJ Basin. We target liquids-rich resource plays and have built our leasehold acreage position through direct acquisitions from mineral owners and other exploration and production companies. Our management team has extensive engineering, geological, geophysical and technical expertise in our operating areas.

 

Our primary area of focus is the East Texas stacked play, in which we owned approximately 71,577 net acres as of July 31, 2014. On July 22, 2014, we completed the purchase of approximately 18,300 net acres in the Ft. Trinidad field in the East Texas stacked play from TreadStone Energy Partners, LLC, including interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells waiting on completion and a 3-well salt water disposal system, for an initial purchase price of approximately $719 million in cash, subject to customary post-closing adjustments. Subsequent to closing, we recognized net negative post-closing adjustments of $26 million, resulting in a cash purchase price of $693 million. The purchase price is subject to additional post-closing adjustments as revenue and expenditures are received and processed. We refer to this transaction as the Ft. Trinidad acquisition. In connection with the consummation of the Ft. Trinidad acquisition, we borrowed $775 million under a senior secured term loan (referred to herein as the senior secured term loan) and issued $375 million principal amount of our 8.00% convertible subordinated notes due 2019 (referred to herein as our convertible notes). We used a portion of the $1.15 billion proceeds from the financings to pay the purchase price for the Ft. Trinidad acquisition, refinance and replace our previously outstanding $225 million principal amount of senior unsecured notes, including a prepayment premium. The results of operations of the Ft. Trinidad acquisition will be included in our consolidated results of operations from the date of acquisition. The Ft. Trinidad acquisition has resulted in a substantial change in the scope of our operations, and we expect the acquisition and related financing to have a material impact on our future results of operations, financial position and cash flows. Accordingly, our historical results of operations and financial position discussed below may not be comparable with our future results of operations and financial position.

 

Giving pro forma effect to the Ft. Trinidad acquisition, as of June 1, 2014, we had total estimated proved reserves of 41,903 MBoe, 11,405 MBoe of which were developed and 30,499 MBoe of which were undeveloped. Pro forma for the Ft. Trinidad acquisition, our average daily net production was approximately 6,016 Boe/day for the three months ended March 31, 2014, approximately 8,363 Boe/day for the three months ended June 30, 2014 and approximately 10,601 Boe/day for the two months ended August 31, 2014. As of August 31, 2014, 13 gross (13 net) wells were waiting on completion on the Ft. Trinidad acreage.

 

We are the operator of approximately 81% of our 71,577 net acres in the East Texas stacked play as of July 31, 2014. We began drilling on our operated East Texas stacked play acreage in May 2013, and we have drilled or were in the process of drilling 18 gross (18 net) operated wells on this acreage as of June 30, 2014. In

 

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addition to our acreage in the East Texas stacked play, as of July 31, 2014 we had approximately 7,089 net acres in the Permian Basin, where we have 100% operated working interests, and 14,162 net acres in the DJ Basin, where we have 100% operated working interests.

 

Prior to the first quarter of 2012, we were engaged primarily in the acquisition and sale of undeveloped oil and natural gas leasehold interests. Beginning in the first quarter of 2012, we adopted a business strategy to develop and exploit our undeveloped leasehold acreage in order to provide a greater return on investments in those properties. At that time, we adopted the full cost method of accounting for oil and natural gas properties.

 

We began accumulating our leasehold acreage in our core areas in early 2011 and began development and exploitation of our acreage in the first quarter of 2012. In April 2013, we completed a significant acquisition of acreage in the East Texas stacked play, which we refer to as the Chesapeake acquisition. Our primary focus is now on the development of our operated acreage in the East Texas stacked play, and the majority of our capital expenditure budget for 2014 and 2015 is focused on the development of this acreage. We began drilling on our operated East Texas stacked play acreage in May 2013, and we have drilled or are in the process of drilling 18 gross (18 net) operated wells on this acreage as of June 30, 2014. In the Ft. Trinidad acquisition, we acquired interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells waiting on completion as of July 22, 2014.

 

In August 2012, we completed a series of transactions that resulted in Energy & Exploration Partners, Inc. becoming a holding company for our business. We refer to these transactions as our corporate reorganization. See “Certain Relationships and Related Party Transactions—Corporate Reorganization.”

 

Factors that Significantly Affect Our Results and How We Evaluate Our Operations

 

As we continue to pursue our strategy of developing and exploiting our leasehold acreage, we expect that our results will be affected significantly by a number of factors, some of which are outside of our control. We discuss our performance based upon these factors and related operational metrics. These factors and metrics include the following, which we discuss in more detail below:

 

   

production volumes;

 

   

realized prices on the sale of oil and natural gas, including the effect of our commodity derivative contracts;

 

   

operating expenses, including lease operating expenses, production taxes, general and administrative expense, impairment and depreciation, depletion and amortization; and

 

   

other income and expenses, including interest expenses, gain on sale of assets and income tax expense.

 

Production Volumes

 

Prior to completion of the Chesapeake acquisition and our subsequent development activity, we had minimal production. As a result of the Chesapeake acquisition during the second quarter of 2013, we acquired interests in nine producing wells, one well awaiting a pipeline connection and one non-producing well in the East Texas stacked play. Additionally, during the period from July 1, 2013 to June 30, 2014 we drilled 16 operated wells and participated in the drilling of three non-operated wells. As a result of these activities, our average daily net production from the East Texas stacked play has increased from 146 Boe/day for the six months ended June 30, 2013 to 1,371 Boe/day for the six months ended June 30, 2014. The Ft. Trinidad acquisition significantly increased our production, as we acquired interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells waiting on completion as of June 1, 2014 in the Ft. Trinidad acquisition. Pro forma for the Ft. Trinidad acquisition, our average daily net production for the six months ended June 30, 2014 was approximately 7,197 Boe/day and estimated average daily net production for the two months ended August 31, 2014 was approximately 10,601 Boe/day. We expect to continue to increase production through further development of our East Texas stacked play acreage. For more information regarding production volumes and drilling plans, see “Business—Our Operations— Production, price and cost history” and “—Capital Budget.”

 

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Realized Prices on the Sale of Oil and Natural Gas

 

Factors Affecting the Sales Price of Oil and Natural Gas.    We market and expect to continue to market our crude oil and natural gas production to a variety of purchasers based on regional pricing. The relative prices of crude oil and natural gas are determined by the factors impacting global and regional supply and demand dynamics, such as economic conditions, production levels, weather cycles and other events. In addition, relative prices are heavily influenced by product quality and location relative to consuming and refining markets.

 

Oil.    The New York Mercantile Exchange—West Texas Intermediate (NYMEX-WTI) futures price is a widely used benchmark in the pricing of domestic crude oil in the United States. The actual prices realized from the sale of crude oil differ from the quoted NYMEX-WTI price as a result of quality and location differentials. Quality differentials to NYMEX-WTI prices result from the fact that crude oils differ from one another in their molecular makeup, which plays an important part in their refining and subsequent sale as petroleum products. Among other things, there are two characteristics that commonly drive quality differentials: (1) the crude oil’s American Petroleum Institute, or API, gravity and (2) the crude oil’s percentage of sulfur content by weight. In general, lighter crude oil (with higher API gravity) produces a larger number of lighter products, such as gasoline, which have higher resale value and, therefore, normally sell at a higher price than heavier oil. Crude oil with low sulfur content (“sweet” crude oil) is less expensive to refine and, as a result, normally sells at a higher price than high sulfur-content crude oil (“sour” crude oil).

 

Location differentials to NYMEX-WTI prices result from variances in transportation costs based on the produced crude oil’s proximity to the major consuming and refining markets to which it is ultimately delivered. Crude oil that is produced close to major consuming and refining markets, such as near Cushing, Oklahoma, is in higher demand as compared to crude oil that is produced farther from such markets. Consequently, crude oil that is produced close to major consuming and refining markets normally realizes a higher price (i.e., a lower location differential to NYMEX-WTI). We believe oil production from the East Texas stacked play can generally be sold at prices that are generally in line with NYMEX-WTI benchmark prices due to the East Texas stacked play’s proximity to the Gulf Coast. For example, for the six months ended June 30, 2014, the average realized price for our oil production was $99.15/Bbl compared to an average NYMEX-WTI index price of $100.81/Bbl for the same period.

 

In the past, crude oil prices have been extremely volatile, and we expect this volatility to continue. For example, the NYMEX-WTI oil price ranged from a high of $110.53/Bbl to a low of $86.68/Bbl during the year ended December 31, 2013 and from a high of $107.26/Bbl to a low of $91.66/Bbl during the six months ended June 30, 2014.

 

Natural Gas.    The NYMEX-Henry Hub price of natural gas is a widely used benchmark for the pricing of natural gas in the United States. Similar to crude oil, the actual prices realized from the sale of natural gas differ from the quoted NYMEX-Henry Hub price as a result of quality and location differentials. Quality differentials to NYMEX-Henry Hub prices result from: (1) the Btu content of natural gas, which measures its heating value, and (2) the percentage of sulfur, CO2 and other inert content by volume. Wet natural gas with a high Btu content sells at a premium to low Btu content dry natural gas because it yields a greater quantity of natural gas liquids (NGLs). Natural gas with low sulfur and CO2 content sells at a premium to natural gas with high sulfur and CO2 content because of the added cost to separate the sulfur and CO2 from the natural gas to render it marketable.

 

Wet natural gas is processed in third-party natural gas plants, and residue natural gas as well as NGLs are recovered and sold. Dry natural gas residue from our properties is generally sold based on index prices in the region from which it is produced.

 

Location differentials to NYMEX-Henry Hub prices result from variances in transportation costs based on the natural gas’s proximity to the major consuming markets to which it is ultimately delivered. Also affecting the differential is the processing fee deduction retained by the natural gas processing plant generally in the form of percentage of proceeds. Generally, these index prices have historically been at a discount to NYMEX-Henry Hub natural gas prices.

 

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In the past, natural gas prices have been extremely volatile, and we expect this volatility to continue. For example, the NYMEX-Henry Hub natural gas price ranged from a high of $4.46 per MMBtu to a low of $3.11 per MMBtu during the year ended December 31, 2013 and from a high of $6.15 per MMBtu to a low of $4.01 per MMBtu during the six months ended June 30, 2014.

 

Commodity Derivative Contracts.    In October 2013, we began a commodity derivative policy designed to minimize volatility in our cash flows from changes in commodity prices. As of August 29, 2014, we had entered into oil and natural gas derivative positions as follows:

 

Year

   Months    Type of
Contract
   Pricing
Index
   Volume
(Bbl/d or
MMBtu/d)
     Swap      Contract Price
($/Bbl or MMBtu)
Weighted Average Price
 
                      Floor              Ceiling      

Crude Oil

                    

2014

   Sep—Dec    Swap    LLS      500       $ 96.24       $ —         $ —     

2014

   Sep—Dec    Swap    WTI      150         95.55         —           —     

2014

   Sep—Dec    Collar    WTI      4,500         —           78.75         100.94   

2015

   Jan—Dec    Collar    LLS      200         —           81.00         98.43   

2015

   Jan—Dec    Collar    WTI      2,650         —           78.71         100.66   

2016

   Jan—Dec    Collar    LLS      200         —           71.75         100.43   

2016

   Jan—Dec    Collar    WTI      1,500         —           78.75         100.94   

Natural Gas

                    

2014

   Jul–Dec    Swap    NYMEX
NG
     500       $ 4.44       $ —         $ —     

 

The production volumes covered by our derivative positions represent approximately 61% of oil production projected through December 2016 from proved developed producing reserves in our June 1, 2014 reserve report pro forma for the Ft. Trinidad acquisition. The agreement governing our senior secured term loan requires us to enter into commodity derivative instruments for specified minimum and maximum levels of anticipated production. Should we reduce our estimates of future production to amounts which are lower than our commodity derivative volumes, we will reduce our positions as soon as practical. If forward crude oil or natural gas prices increase to prices higher than the prices at which we have entered into commodity derivative positions, we may be required to make margin calls out of our working capital in the amounts those prices exceed the prices we have entered into commodity derivative positions. We do not intend to enter into commodity derivative transactions for the purpose of speculative trading.

 

Operating Expenses

 

Operating expenses consist of lease operating expense, production taxes, general and administrative expense, full cost ceiling impairment, impairment and abandonment of unproved properties and depreciation, depletion and amortization (DD&A). We discuss impairments and DD&A under the full cost method of accounting below under “—Critical Accounting Policies and Estimates—Oil and Natural Gas Properties.”

 

Lease Operating Expense.    Lease operating expense consists primarily of oil and natural gas production expenses, ad valorem taxes and workover expenses.

 

Oil and natural gas production expenses are the costs incurred in the operation of producing properties and workover costs. We expect expenses for utilities, direct labor, water injection and disposal, and materials and supplies to comprise the most significant portion of our oil and natural gas production expenses. Oil and natural gas production expenses do not include general and administrative costs or production and other taxes. Certain items, such as direct labor and materials and supplies, generally remain relatively fixed across broad production volume ranges, but can fluctuate depending on activities performed during a specific period. For instance, repairs to our pumping equipment or surface facilities may result in increased oil and natural gas production expenses in periods during which they are performed.

 

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A majority of our operating cost components will be variable and increase or decrease as the level of produced hydrocarbons and water increases or decreases. For example, we will incur power costs in connection with various production related activities such as pumping to recover oil and natural gas and separation and treatment of water produced in connection with our oil and natural gas production. Over the life of hydrocarbon fields, the amount of water produced may increase for a given volume of oil or gas production, and, as pressure declines in natural gas wells that also produce water, more power will be needed to provide energy to artificial lift systems that help to remove produced water from the wells. Thus, production of a given volume of hydrocarbons may become more expensive each year as the cumulative oil and natural gas produced from a field increases until, at some point, additional production becomes uneconomic.

 

Ad valorem taxes are included in lease operating expense and are generally tied to the valuation of oil and natural gas properties; however, these valuations are reasonably correlated to revenues, excluding the effects of any commodity derivative contracts.

 

Production Taxes.    Texas regulates the development, production, gathering and sale of oil and natural gas, including imposing production taxes and requirements for obtaining drilling permits. For oil production, Texas currently imposes a production tax of 4.6% of the market value of the oil produced and an additional 3/16 of one cent per barrel of crude petroleum produced, and for natural gas, Texas currently imposes a production tax of 7.5% of the market value of the natural gas produced.

 

General and Administrative Expense.    Currently our general and administrative expense primarily consist of employee related costs, share-based compensation and professional fees. We expect that general and administrative expense will increase following the closing of this offering when we will be a publicly traded company. General and administrative expense related to being a publicly traded company includes: Exchange Act reporting expenses; expenses associated with Sarbanes-Oxley compliance; expenses associated with listing on a national securities exchange; independent auditor fees; legal fees; investor relations expenses; registrar and transfer agent fees; director and officer liability insurance costs; and director compensation.

 

Other Income and Expenses

 

Our other income and expenses consist primarily of loss on early extinguishment of debt, interest expense, loss on derivatives, gain on sale of assets and income tax expense.

 

Loss on Early Extinguishment of Debt.    During each of 2013 and 2012, we paid off our indebtedness related to then-existing credit facilities. As a result, we recorded a loss on the early extinguishment of debt of $3.7 million and $1.0 million for the years ended December 31, 2013 and 2012, respectively. The loss recognized in both periods consists of a make-whole payment made to retire the debt and the elimination of unamortized debt issuance costs. Additionally, during July 2014, we refinanced and replaced our senior unsecured notes resulting in a loss of approximately $76.7 million on the early extinguishment of debt, including a prepayment penalty, which will be reflected in our financial statements during the third quarter of 2014.

 

Interest Expense.    We have financed and expect to continue to finance a portion of our working capital requirements, capital expenditures and acquisitions with borrowings under our debt facilities and notes. See “—Liquidity and Capital Resources—Debt Facilities and Notes.” As a result, we incur interest expense that is affected by both fluctuations in interest rates and our financing decisions. Interest expense includes interest paid to our lenders. In addition, we include the amortization of deferred financing costs (including origination and amendment fees), commitment fees and annual agency fees in interest expense. As a result of the significant increase in our indebtedness as a result of the issuance of the convertible notes and the senior secured term loan, our interest expense will increase significantly in the future in comparison to prior periods.

 

Loss on Derivatives.    We initiated a commodity derivative policy during 2013 to utilize various derivative instruments to economically hedge our exposure to oil and natural gas price volatility. Additionally, the

 

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agreement governing our senior secured term loan requires us to enter into commodity derivative instruments for a minimum of 40% and maximum of 80% of anticipated production from our proved reserves. During 2013 and 2014 we entered into arrangements for fixed price swaps and costless collars (puts and calls) to economically hedge future oil and natural gas prices and comply with our debt instrument requirements. We have not designated any of our derivative instruments as hedges; therefore, the derivatives are carried at fair value on the consolidated balance sheets as assets or liabilities, and all changes in fair value are recorded as gains and losses in the statements of operations. During the year 2013, we experienced a loss on derivatives of $0.7 million of which $0.6 million related to unrealized losses and $0.1 million related to realized loss on derivatives. During the six months ended June 30, 2014, we experienced a loss on derivatives of $2.2 million of which $1.3 million related to unrealized loss and $0.9 million related to realized loss on derivatives.

 

Gain on Sale of Assets.    During 2013 and 2012, we entered into agreements pursuant to which we sold working interests in our DJ Basin properties located in Colorado and a substantial portion of the East Texas stacked play acreage we owned prior to the Chesapeake acquisition. Our results include gains on the sale of assets related primarily to these this transactions.

 

Income Tax Expense.    Prior to April 13, 2012, our properties were owned by Energy & Exploration Partners, LLC, or ENXP LLC, a limited liability company that elected to be taxed as an S corporation and therefore was not a taxable entity and did not directly pay federal income taxes. Accordingly, no provision for federal corporate income taxes has been provided for the period from February 14, 2006, the date of our inception, to December 31, 2011, or for the period from January 1, 2012 to April 13, 2012, as taxable income was allocated directly to our equity holders.

 

Our income tax expense in our historical financial statements for periods prior to April 13, 2012 results from the State of Texas margin tax that applies to entities organized as partnerships or limited liability companies.

 

On April 13, 2012, ENXP LLC terminated its election to be treated as an S corporation and became a C corporation for federal income tax reporting purposes. Accordingly, as of that date we became, and after our corporate reorganization continue to be, subject to federal income taxes, which may affect future operating results and cash flows. In connection with our becoming a C corporation, an estimated net deferred tax liability of approximately $1.1 million was established for differences between the book and tax basis of our assets and liabilities and a corresponding expense was recorded to net income from operations.

 

Our income tax subsequent to April 13, 2012 included provisions for both federal and state income tax benefits (expenses) using the asset and liability method wherein deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between financial statement carrying amounts and the respective tax basis of the existing assets and liabilities as measured using enacted tax rates applicable to each tax jurisdiction. Additionally, we include penalty and interest expenses assessed on tax filings in income tax expense.

 

Results of Operations

 

The discussion of our results of operations and period to period comparisons presented below analyze our historical results, which may not be indicative of future results. The Ft. Trinidad acquisition substantially expanded the scope of our operations, and we expect it to have a material impact on our future results of operations. Accordingly, our historical results of operations discussed below may not be comparable with our future results of operations.

 

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Six Months Ended June 30, 2014 Compared to Six Months Ended June 30, 2013

 

Production and Oil and Natural Gas Sales

 

The following table summarizes our oil and natural gas production volumes and average sales prices for the six months ended June 30, 2013 and 2014.

 

     Six Months Ended June 30,  
             2013                      2014          

Production Volumes

     

Oil (Bbls)

     18,296         201,771   

Natural gas liquids (Bbls)

     782         23,172   

Natural gas (Mcf)

     44,168         139,570   

Total (BOE)

     26,439         248,205   

Average realized prices:

     

Oil (Bbls)

   $ 95.03       $ 99.15   

Natural gas liquids (Bbls)

     20.94         31.22   

Natural gas (Mcf)

     4.23         3.71   

Total (BOE)

     73.45         85.61   

 

Oil and gas sales increased $19.3 million for the six months ended June 30, 2014 from $1.9 million during the six months ended June 30, 2013 to $21.2 million during the six months ended June 30, 2014. The increase was primarily due to increased production resulting from the drilling and completion of 19 gross producing wells, including 16 operated and three non-operated wells subsequent to June 30, 2013. Realized average prices increased $12.14, or 17%, to $85.61 per Boe for the six months ended June 30, 2014 compared to the prior period.

 

Operating Expenses

 

Lease Operating Expense.    Lease operating expense was $4.4 million for the six months ended June 30, 2014, compared to $0.3 million for the six months ended June 30, 2013. The increase in lease operating expenses was due to the increase in the number of producing wells subsequent to June 30, 2013.

 

Production Taxes.    Production taxes increased by approximately $1.0 million from $0.1 million for the six months ended June 30, 2013 to $1.1 million for the six months ended June 30, 2014. The increase was primarily due to an increase in revenues resulting from an increase in production volumes sold from 26,439 Boe for the six months ended June 30, 2013 to 248,205 Boe for the six months ended June 30, 2014. Production taxes were approximately 5% of oil and natural gas sales for the six months periods ended June 30, 2014 and 2013.

 

Full-Cost Ceiling Impairment.    We did not record a full cost ceiling impairment for the six months ended June 30, 2014. Full cost ceiling impairment was $8.4 million for the six months ended June 30, 2013 due to $8.4 million excess in carrying costs associated with our oil and natural gas properties over the estimated ceiling limit on the book value of our oil and natural gas properties during the first quarter of 2013. Prior to the Chesapeake acquisition and the full implementation of our 2013 drilling program, we had reserves on a limited number of properties, which resulted in a low limit of our ceiling threshold. We participated in the drilling of two non-operated wells that were dry holes during the first quarter of 2013 that were included in the full cost pool with no corresponding reserves recorded. The dry hole costs were the primary contributor to the first quarter 2013 full-cost ceiling impairment.

 

General and Administrative Expense.    General and administrative expense increased by approximately $0.1 million from $8.7 million for the six months ended June 30, 2013 to $8.8 million for the six months ended June 30, 2014. This increase was primarily due to an increase in employee related costs of $2.0 million, third party professional fees of $2.5 million, and other net administrative costs of $0.7 million for the six months

 

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ended June 30, 2014 compared to the six months ended June 30, 2013, primarily related to our expanding employee base and the growth in our business. These increases were partially offset by a $5.1 million decrease in share based compensation expense for the six months ended June 30, 2014 compared to the six months ended June 30, 2013, primarily due to certain shares fully vesting in prior periods.

 

Depletion, Depreciation and Amortization Expense.    Depletion, depreciation and amortization increased by approximately $8.3 million from $1.2 million for the six months ended June 30, 2013 to $9.5 million for the six months ended June 30, 2014. The increase was primarily due to an increase in production during 2014 compared to the prior period, partially offset by a decrease in the depletion rate per Boe to $37.51 for the six months ended June 30, 2014 from $41.61 for the six months ended June 30, 2013. The decrease in the depletion rate per Boe during the six months ended June 30, 2014 was primarily due to an increase in proved reserves, partially offset by an increase in the amortization base of costs. Our reserves increased 292% to 9.2 MMBoe at June 1, 2014 compared to 2.3 MMBoe at June 30, 2013.

 

Other Income and Expenses

 

The following table summarizes other income and expenses for the periods indicated (in thousands):

 

     Six Months Ended
June 30,
       
     2013     2014     Variance  

Other income (expense)

      

Interest and other income

   $ 33      $ 4      $ (29

Interest expense

     (7,132     (13,174     (6,042

Loss on early extinguishment of debt

     (3,677     —          3,677   

Loss on derivatives

     —          (2,174     (2,174

Gain (loss) on sales of assets

     14,275        14,249        (26
  

 

 

   

 

 

   

 

 

 

Total other income (expense), net

   $ 3,499      $ (1,095   $ (4,594
  

 

 

   

 

 

   

 

 

 

 

Interest expense.     Interest expense increased approximately $6.0 million from $7.1 million for the six months ended June 30, 2013 to $13.2 million for the six months ended June 30, 2014. This increase was primarily due to increased interest and amortization of debt discounts and loan costs associated with higher debt levels during 2014, partially offset by an increase in capitalized interest. Capitalized interest increased $5.3 million from $0.1 million for the six months ended June 30, 2013 to $5.4 million for the six months ended June 30, 2014.

 

Loss on early extinguishment of debt.    Loss on early extinguishment of debt was approximately $3.7 million for the six months ended June 30, 2013. The loss relates to the prepayment penalty and expensing of the unamortized debt issuance costs from the early payoff of our Guggenheim credit facility in April 2013. For the six months ended June 30, 2014, we incurred no loss on early extinguishment of debt.

 

Loss on Derivatives.    Loss on derivatives was approximately $2.2 million for the six months ended June 30, 2014. The loss on derivatives was composed of $0.9 million in realized loss and $1.3 million in change in fair value of derivatives. The $0.9 million in realized loss relates to settlement of oil and natural gas positions for our January through June 2014 production periods. The $1.3 million change in fair value of derivatives reflects the change in fair value of our unsettled derivative positions resulting primarily from an increase in estimated future oil prices. We initially entered into derivative instruments subsequent to June 30, 2013; therefore, there were no derivative gains or losses during the six months ended June 30, 2013.

 

Gain (Loss) on Sales of Assets.    Gain on sale of assets decreased approximately $26,000 from $14.3 million for the six months ended June 30, 2013 to $14.2 million for the six months ended June 30, 2014.

 

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The gains recognized represent additional sales proceeds related to contingent payments received from one of our operating partners related to a sale of unevaluated properties in 2012, but for which the contingent requirements were not met until subsequent periods.

 

Income Tax Benefit

 

Income tax benefit decreased approximately $3.6 million from a $3.9 million income tax benefit for the six months ended June 30, 2013 to $0.3 million income tax benefit for the six months ended June 30, 2014. This decrease in income tax benefit was primarily due to a decrease in net loss for the six month period ended June 30, 2014 as compared to the prior period, partially offset by a $1.1 million increase in our valuation allowance and a $1.5 million decrease in penalty and interest between the comparable periods. During the six months ended June 30, 2013, we accrued penalty and interest of $0.9 million compared to a reduction of $0.5 million in penalty and interest during the six months ended June 30, 2014.

 

Year Ended December 31, 2013 Compared to Year Ended December 31, 2012

 

Production and Oil and Natural Gas Sales

 

The following table summarizes our oil and natural gas production volumes and average sales prices for the years ended December 31, 2013 and 2012.

 

     Year Ended December 31,  
             2012                      2013          

Production Volumes:

     

Oil (Bbls)

     2,247         161,579   

Natural gas liquids (Bbls)

     383         5,123   

Natural gas (Mcf)

     3,903         128,603   

Total (BOE)

     3,281         188,136   

Average realized prices:

     

Oil (Bbls)

   $ 87.58       $ 98.02   

Natural gas liquids (Bbls)

     27.78         26.02   

Natural gas (Mcf)

     2.17         3.62   

Total (BOE)

     65.81         87.37   

 

Oil and gas sales increased $16.2 million during the year ended December 31, 2013 to $16.4 million compared to $0.2 million for the prior year. The increase is primarily due to increased production during 2013 resulting from the addition of 25 gross producing wells, including nine operated and five non-operated wells drilled and completed during 2013 and the acquisition of 11 wells in our April 2013 Chesapeake acquisition. This increase in producing wells is partially offset by the sale of two gross wells during June 2013.

 

The average realized sales price for oil was $98.02/Bbl for the year ended December 31, 2013, an increase of 12%, compared to $87.58/Bbl for 2012. The price received on our oil sales during the year ended December 31, 2013 of $98.02/Bbl was the average months’ NYMEX-WTI prices adjusted for differentials determined on a locational basis and other market factors. The simple daily average NYMEX-WTI price for the year ended December 31, 2013 was $98.01.

 

The average realized sales price for natural gas was $3.62/Mcf for the year ended December 31, 2013, an increase of 67%, compared to $2.17/Mcf for 2012. The price received on our natural gas sales during year ended December 31, 2013 of $3.62/Mcf was the average month’s Henry Hub natural gas spot price adjusted for differentials determined on a locational basis, liquids Btu content and other market factors. The simple daily average Henry Hub natural gas spot price for the year ended December 31, 2013 was $3.73/Mcf.

 

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Operating Expenses

 

Lease Operating Expense.    Lease operating expense was $3.2 million for the year ended December 31, 2013, compared to $11,000 for the year ended December 31, 2012. The increase in lease operating expense is due to the increase in the number of producing wells from three gross productive wells at December 31, 2012 to 26 gross productive wells at December 31, 2013. Our first producing wells began production in March 2012, and, as a result, we had de minimis lease operating expenses associated with the three wells producing during 2012.

 

Production Taxes.    Production taxes increased by approximately $0.9 million from $14,000 for the year ended December 31, 2012 to $0.9 million for the year ended December 31, 2013. The increase in primarily due to an increase in production volumes sold from 3,281 Boe during 2012 to 188,136 Boe during 2013.

 

Full-Cost Ceiling Impairment.    Full cost ceiling impairment was $8.4 million for the year ended December 31, 2013 due to an $8.4 million excess in carrying costs associated with our oil and natural gas properties (net of amortization) over the estimated ceiling limit on the book value of our oil and natural gas properties. During the first quarter of 2013, prior to our Chesapeake acquisition and the full implementation of our 2013 drilling program, we had reserves on a limited number of properties, which resulted in a low limit on our ceiling threshold. We participated in the drilling of two non-operated wells that were dry holes during the first quarter of 2013 that were included in the full cost pool with no corresponding reserves recorded. The dry hole costs were the primary contributor to the 2013 impairment. Full cost ceiling impairment was $4.0 million for the year ended December 31, 2012 due to a $4.0 million excess in carrying costs associated with our oil and natural gas properties (net of amortization) over the estimated ceiling limit on the book value of our oil and natural gas properties. During the fourth quarter of 2012, we had reserves on a limited number of properties, which resulted in a low limit on our ceiling threshold. We participated in the drilling of one non-operated well that was a dry hole during the fourth quarter of 2012 that was included in the full cost pool with no corresponding reserves recorded. The dry hole cost was the primary contributor to the 2012 impairment.

 

General and Administrative Expense.    General and administrative expense increased by approximately $6.4 million from $10.5 million for the year ended December 31, 2012 to $16.9 million for the year ended December 31, 2013. Of the $6.4 million increase, $5.2 million related to non-cash share-based compensation expense related to awards granted under our 2012 Stock Incentive Plan, which was established in the third quarter of 2012. Excluding share-based compensation expense, general and administrative expense increased $1.2 million primarily due to increased employee related costs associated with our expanding employee base, partially offset by a decrease in third-party professional fees.

 

Depletion, Depreciation and Amortization Expenses.    Depletion, depreciation and amortization increased by approximately $6.4 million from $0.5 million for the year ended December 31, 2012 to $6.9 million for the year ended December 31, 2013. The increase is primarily due to an increase in production during 2013 compared to the prior period. Additionally, the depletion rate per Boe for the year ended December 31, 2013 declined to $35.38 compared to $93.48 for the prior period. At December 31, 2013, we had 19.6 net producing wells compared to 0.3 net wells producing at December 31, 2012. The decline in the depletion rate per Boe during the year ended December 31, 2013 is primarily due to the addition of proved reserves resulting from wells drilled and acquired wells during 2013. Our reserves increased 22,328% to 7.1 MMBoe at December 31, 2013 compared to 31,500 Boe at December 31, 2012.

 

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Other Income and Expenses

 

The following table summarizes other income and expense for the periods indicated (in thousands):

 

     Year Ended
December 31,
       
     2012     2013     $ Variance  

Other income (expense)

      

Interest and other income

   $ 10      $ 53      $ 43   

Loss on early extinguishment of debt

     (985     (3,677     (2,692

Interest expense

     (2,842     (17,211     (14,369

Loss on derivatives

     —          (662     (662

Gain on sales of assets

     34,738        14,275        (20,463
  

 

 

   

 

 

   

 

 

 

Total other income (expense), net

   $ 30,921      $ (7,222   $ (38,143
  

 

 

   

 

 

   

 

 

 

 

Loss on Early Extinguishment of Debt.    Loss on early extinguishment of debt increased approximately $2.7 million from $1.0 million for the year ended December 31, 2012 to $3.7 million for the year ended December 31, 2013. This increase is primarily due to the payoff of a previously existing credit facility during 2013. The $3.7 million recognized as a loss consists of a make-whole payment of $2.8 million to retire the credit facility and the elimination of $0.9 million unamortized debt issuance costs related to this facility. In 2012, we recorded a loss on debt extinguishment of $1.0 million related to the expensing of our unamortized debt issuance costs upon termination of a $10 million 14% senior secured note.

 

Interest Expense.    Interest expense increased approximately $14.4 million from $2.8 million for the year ended December 31, 2012 to $17.2 million for the year ended December 31, 2013. This increase is primarily due to increased interest and amortization of loan costs associated with higher debt levels during 2013. These increases were partially offset by an increase in capitalized interest of $3.8 million during 2013. During April 2013, we issued our senior unsecured notes in the amount of $140.0 million and used a portion of the proceeds of the issuance of the senior unsecured notes to retire our then existing credit facility. In addition, during April 2013, we issued the $18.0 million subordinated Chesapeake note as payment for a portion of the purchase price for the Chesapeake acquisition. In December 2013, we issued an additional $25.0 million of our senior unsecured notes.

 

Loss on Derivatives.    Loss on derivatives was approximately $0.7 million for the year ended December 31, 2013. Loss on derivatives is composed of $0.1 million in realized loss and $0.6 million in unrealized loss. The $0.1 million of realized loss relates to settlement of oil positions for our November and December 2013 production periods. The $0.6 million unrealized loss reflects the change in fair value on our oil positions for production periods subsequent to 2013 resulting primarily from an increase in estimated future oil prices. We initially entered into derivative instruments subsequent to December 31, 2012; therefore, there were no derivative gains or losses during the year ended December 31, 2012.

 

Gain on Sales of Assets.    Gain on sales of assets decreased by approximately $20.5 million from $34.7 million for the year ended December 31, 2012 to $14.3 million for the year ended December 31, 2013. The $34.7 million gain for the year ended December 31, 2012 was related to the sale of a 75% to 85% working interest in certain of our unevaluated East Texas stacked play acreage. The $14.6 million gain on sale of assets for the year ended December 31, 2013 represents additional sales proceeds related to a $14.6 million contingent payment, net of related expenses, received from one of our operating partners related to a sale of unevaluated properties in 2012, but for which the contingent requirements were not met until March 2013.

 

Income Tax Expense

 

Income tax expense decreased by approximately $12.8 million from a tax expense of $7.4 million for the year ended December 31, 2012 to a tax benefit of $5.4 million for the year ended December 31, 2013. This

 

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decrease in income tax expense is primarily due to a decrease in net income before tax of $43.3 million for the year ended December 31, 2013 compared to the prior year. The tax benefit recorded for the year ended December 31, 2013 was partially offset by a $2.2 million valuation allowance recorded during 2013 due to our uncertainty surrounding the future use of our tax attributes.

 

Year Ended December 31, 2012 Compared to Year Ended December 31, 2011

 

Production and Oil and Natural Gas Sales

 

Net production was 3,281 Boe and oil and natural gas sales was $0.2 million for the year ended December 31, 2012. We had no production or oil and natural gas revenues in the year ended December 31, 2011. The production and revenues in 2012 were solely related to the change in our business focus during 2012 from the purchase and sale of leases to the acquisition, exploration, development, exploitation and production of unconventional oil and natural gas resources. During 2012, we had working interests in three producing wells. Production on our first well began in March 2012.

 

The price received on our oil sales during 2012 of $87.58 was the average month’s NYMEX-WTI prices adjusted for differentials. The average NYMEX-WTI price for the ten months ended December 31, 2012 was $92.78.

 

The price received on our natural gas sales during 2012 of $2.17 per Mcf was the average month’s Henry Hub natural gas spot price adjusted for differentials. The average Henry Hub natural gas spot price for the ten months ended December 31, 2012 was $2.79.

 

Operating Expenses

 

Lease Operating Expense.    Lease operating expense was approximately $11,000 for the year ended December 31, 2012. The lease operating expense in 2012 is solely related to the change in our business focus during 2012 from the purchase and sale of leases to the acquisition, exploration, development, exploitation and production of unconventional oil and natural gas resources. We had no working interests in producing wells during the year ended December 31, 2011 and, therefore, had no corresponding lease operating expense.

 

Production Taxes.    Production tax was approximately $10,000 for the year ended December 31, 2012. Production tax in 2012 is solely related to the change in our business focus during 2012 from the purchase and sale of leases to the acquisition, exploration, development, exploitation and production of unconventional oil and natural gas resources. We had no working interests in producing wells during the year ended December 31, 2011 and, therefore, had no corresponding production taxes.

 

Impairment and Abandonment of Unproved Properties.    We had no impairment of unevaluated properties in the year ended December 31, 2012. Impairment of unevaluated properties was $0.7 million for the year ended December 31, 2011. The $0.7 million impairment within our unevaluated properties related to leases that were abandoned or leases in which we deemed it unlikely to recover our full investment at December 31, 2011.

 

Full-Cost Ceiling Impairment.    Full-cost ceiling impairment was approximately $4.0 million for the year ended December 31, 2012. During 2012 we recorded our initial investment in proved properties and also recorded a full-cost ceiling impairment of approximately $4.0 million in the same period related to the full-cost ceiling limitation on the properties in our full-cost pool. We had no full cost ceiling impairment during the year ended December 31, 2011.

 

The full-cost ceiling impairment impacts the accumulated depletion and the net carrying value of the assets on our balance sheet, as well as the corresponding shareholders’ equity, but it has no impact on our net cash flows as reported.

 

General and Administrative Expense.    General and administrative expense increased approximately $9.4 million from $1.1 million for the year ended December 31, 2011 to $10.5 million for the year ended

 

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December 31, 2012. Non-cash share-based compensation expense related to restricted share awards was approximately $3.9 million in 2012. There was no share-based compensation expense in 2011. Excluding share- based compensation in 2012, general and administrative expenses increased $5.5 million due to a combination of factors including increased head count, increases in professional fees, contract labor and consulting fees.

 

Depletion, Depreciation and Amortization Expenses.    In 2012 our initial proved property investments resulted in the recognition of depletion expense associated with the drilling and completion of wells placed into production during 2012.

 

Depletion, depreciation and amortization, or DD&A, increased by approximately $0.4 million from $0.03 million for the year ended December 31, 2011 to $0.4 million for the year ended December 31, 2012, of which $0.3 million relates to depletion on evaluated properties. During the year ended December 31, 2012 we had three producing wells subject to amortization compared to no producing wells for the year ended December 31, 2011. The remaining $0.1 million increase relates to increased depreciation expense on our office equipment, furniture and fixtures due to increased purchases of furniture and fixtures during the year to support increased personnel.

 

Other Income and Expenses

 

The following table summarizes other income and expenses for the periods indicated (in thousands):

 

     Year Ended
December 31,
       
     2011     2012     $ Variance  

Other income (expense)

      

Interest and other income

   $ 25      $ 10      $ (15

Loss on early extinguishment of debt

     —          (985     (985

Interest expense

     (270     (2,842     (2,572

Gain on sales of assets

     573        34,738        34,165   
  

 

 

   

 

 

   

 

 

 

Total other income (expense), net

   $ 328      $ 30,921      $ 30,593   
  

 

 

   

 

 

   

 

 

 

 

Loss on Early Extinguishment of Debt.    Loss on early extinguishment of debt was approximately $1.0 million for the year ended December 31, 2012. During the second quarter of 2012, we repaid our indebtedness under a $10 million 14% senior secured note. The $1.0 million recognized as a loss consists of the expensing of unamortized debt issuance costs related to the early termination of this note as well as the termination of a proposed note.

 

Interest expense.    Interest expense increased approximately $2.6 million from $0.3 million for the year ended December 31, 2011 to $2.8 million for the year ended December 31, 2012. This increase is primarily due to increased interest and amortization of loan costs associated with higher debt levels during the 2012 period. These increases were partially offset by an increase in capitalized interest of $0.2 million during the 2012 annual period.

 

At December 31, 2011, we had indebtedness of $10.0 million under a $10 million 14% senior secured note. During the second quarter of 2012, we repaid this note and replaced it with a $100.0 million senior secured advancing line of credit, with a 15% variable rate and an initial $30 million borrowing base. The outstanding balance on this line of credit, which we refer to as the Guggenheim credit facility, was $21.3 million at December 31, 2012.

 

Gain on Sales of Assets.    Gain on sales of assets increased by approximately $34.1 million from $0.6 million for the year ended December 31, 2011 to $34.7 million for the year ended December 31, 2012. This increase is a result of our sales of working interests in our East Texas stacked play area. We follow the full cost method of accounting for our oil and gas properties. Generally, under this method, sales are accounted for as adjustments to capital cost, with no gains or losses realized, unless such adjustments would significantly alter the relationship

 

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between capitalized costs and proved reserves of the cost center. These sales transactions significantly altered the basis between the capitalized costs of our properties and our reserves at the time of the sales. The properties sold as part of these transactions were our interests in unevaluated leases with no determinable reserves. As a result, proceeds received from the sale were applied against our basis in the unevaluated leases, resulting in $0 basis for these properties as of December 31, 2012. A gain on the sale was recognized to the extent the proceeds exceeded the basis. Proceeds from these transactions amounted to approximately $78.0 million, which were offset by approximately $43.3 million in the cost of the unevaluated leases.

 

Income Tax Expense

 

Income tax expense increased by approximately $7.4 million from $0.03 million for the year ended December 31, 2011 to $7.4 million for the year ended December 31, 2012.

 

As discussed above, prior to April 13, 2012, our properties were owned by a limited liability company, which was treated as an S corporation for federal income tax purposes, and therefore was not a taxable entity and did not directly pay federal income taxes. Accordingly, no provision for federal income taxes has been provided for the period from February 14, 2006, the date of our inception, to December 31, 2011, or for the period from January 1, 2012 to April 13, 2012, as taxable income was allocated directly to our equity holders.

 

Our income tax expense for the year ended December 31, 2011 results solely from the Texas margin tax.

 

Liquidity and Capital Resources

 

Through June 30, 2014 our primary sources of liquidity have been associated with sales of leasehold acreage positions, borrowings under debt facilities and cash flows from operations.

 

Significant Asset Sales

 

During 2012, we received proceeds of approximately $78.0 million related to the sale of acreage positions in certain East Texas stacked play acreage.

 

During 2013, we received a contingent payment of approximately $14.6 million related to the sale of acreage positions in 2012 but for which the contingent requirements were not met until March 2013.

 

Also in 2013, we sold our DJ Basin assets located in Weld County, Colorado for consideration of approximately $5.5 million in cash, subject to customary purchase price adjustments. The divested assets include approximately 2,648 net acres and two gross (0.1 net) non-operated wells.

 

During March 2014, we recorded an additional contingent payment of approximately $14.6 million related to the sale of acreage positions in 2012 but for which the contingent requirements were met in March 2014. We received the cash payment during May 2014.

 

During June 2014, the Company completed the disposition of certain oil and gas leaseholds in Houston and Robertson Counties, Texas, to several oil and gas companies for sales proceeds of approximately $5.4 million in cash.

 

Prior Debt Facilities and Notes

 

Senior Secured Note.    During 2012, prior to its retirement, we had a senior secured note that had borrowings totaling $15.0 million which were used to fund leasehold acquisitions and our share of operating costs with our operating partners. We repaid this note on June 26, 2012 with borrowings under our Guggenheim credit facility, under which we initially borrowed $21.5 million to repay the senior secured note, increase our working capital and fund a portion of our drilling and completion program.

 

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Senior Unsecured Notes.    On April 8, 2013, we issued senior unsecured notes to affiliates of Highbridge Principal Strategies, LLC, or Highbridge, and Apollo Investment Corporation, or Apollo, in the aggregate principal amount of $140.0 million. We used a portion of the net proceeds from these senior unsecured notes to fund a portion of the cash purchase price for the Chesapeake acquisition, to repay indebtedness under our Guggenheim credit facility and to fund drilling and development of our East Texas stacked play acreage. On December 12, 2013, January 31, 2014 and March 27, 2014, we issued $25.0 million, $15.0 million and $45.0 million, respectively, of additional senior unsecured notes to Highbridge and Apollo. We used the net proceeds from the sale of the additional senior unsecured notes to fund drilling and development of our East Texas stacked play acreage. We refinanced and replaced all of the senior secured notes on July 22, 2014 with the net proceeds of our senior secured term loan and convertible notes, which required payment of a prepayment premium of $52.6 million. We also entered into a secured term loan agreement with Highbridge and Apollo in August 2013, but did not borrow under the term loan. The term loan agreement was terminated on July 22, 2014.

 

Debt Facilities and Notes

 

Chesapeake Note.    In April 2013, as part of the purchase price for the Chesapeake acquisition, we issued to an affiliate of Chesapeake Energy Corporation a promissory note in the original principal amount of $18.0 million, which we refer to as the Chesapeake note. The Chesapeake note matures on the earlier of (1) October 8, 2018, (2) the closing of our initial public offering or (3) six months after the date of repayment of our senior debt (as defined in the Chesapeake note) in full. The Chesapeake note bears interest at 10% per annum until our senior debt is paid in full and 15% thereafter. Until our senior debt is paid in full, all interest on the Chesapeake note is paid in kind. As of June 30, 2014, the principal amount outstanding on the Chesapeake note was approximately $20.3 million. We plan to repay the Chesapeake note in full with the net proceeds from this offering. See “Use of Proceeds.”

 

Convertible Notes.    On July 22, 2014, contemporaneously with the closing of the TreadStone Ft. Trinidad acquisition and the senior secured term loan, we issued $375 million of our 8.0% convertible subordinated notes due 2019 in a private placement transaction. We used a portion of the net proceeds of the convertible notes offering, along with the net proceeds from the senior secured term loan, to refinance and replace our senior unsecured notes. We expect to use the remaining net proceeds to fund a portion of our 2014 and 2015 capital expenditure budget for drilling and developing our leasehold acreage, acquire additional oil and gas leases, extend expiration of our current leasehold acreage and acquire 3D seismic data, for general corporate purposes and to pay fees and expenses in connection with the foregoing.

 

The convertible notes bear interest at a rate of 8.0% per annum subject to semi-annual increases of 0.50% beginning on July 1, 2015 if a preliminary prospectus under the Securities Act with a bona fide price range in connection with a qualified public offering (as defined below) has not been filed by each such date and, in each case, the qualified public offering has not priced within 60 days after the date of such scheduled interest rate increase.

 

Holders of the convertible notes may elect to convert their notes into shares of our common stock at a specified conversion price in connection with the closing of a qualified public offering. A qualified public offering is defined as the first public offering of our common stock in which the aggregate gross proceeds to us and any selling stockholders equals or exceeds $400.0 million and following which our common stock is listed on a U.S. national securities exchange. We expect this offering will constitute a qualified public offering.

 

The number of shares of common stock issuable upon conversion of the convertible notes will be the greater of:

 

   

the number of shares of common stock determined by dividing (1) the principal amount of the convertible notes converted by (2) a conversion price that is equal to a specified percentage of the public offering price per share in the qualified public offering that decreases over time, which percentage will be 90% assuming this offering is consummated on or before December 31, 2014; and

 

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a number of shares of common stock that represents a percentage of our outstanding shares of common stock immediately prior to the consummation of a qualified public offering (giving effect to the conversion of the convertible notes and all other securities that are convertible into shares of our common stock, but before the issuance by us of shares in the qualified public offering) that is equal to (1) the principal amount of the convertible notes converted divided by (2) $900 million.

 

Holders of the convertible notes may elect to convert their convertible notes during the period commencing September 15, 2014 and ending on October 28, 2014. Following the completion of a qualified public offering, we may redeem, and intend to redeem, any convertible notes not converted at a price equal to 100% of the principal amount of the convertible notes redeemed, plus accrued interest. Accordingly, we expect that all of the convertible notes will be converted in connection with this offering. Assuming the conversion of all of the convertible notes and an initial public offering price of $         per share of our common stock in this offering (the midpoint of the price range set forth on the cover page of this prospectus), the convertible notes will convert into             shares of our common stock upon completion of this offering. A $1.00 increase in the initial public offering price per share would decrease the number of shares issuable upon conversion of the convertible notes by             shares, and a $1.00 decrease in the initial public offering price per share would increase the number of shares issuable upon conversion of the convertible notes by             shares.

 

Holders of the convertible notes have certain registration rights with respect to the shares of common stock issuable upon conversion of the convertible notes, including piggyback registration rights that permit holders to sell up to an aggregate 36% of those shares of common stock in a qualified public offering. We expect that some or all of the convertible note holders will exercise their rights to sell shares in this offering. The remaining shares not sold in a qualified public offering will be subject to a 180-day lockup. See “Principal and Selling Stockholders.”

 

Senior Secured Term Loan.    On July 22, 2014, contemporaneously with the closing of the TreadStone Ft. Trinidad acquisition and the offering of the convertible notes, we entered into the agreement governing the senior secured term loan with a group of institutional lenders and borrowed $775 million under the senior secured term loan. The senior secured term loan matures on January 22, 2019 and provided for an original principal amount of $775 million. Subject to certain conditions, including obtaining the participation of existing or prospective lenders, we may incur incremental term loans in an amount up to $175 million.

 

Our wholly owned subsidiary, ENXP LLC, is the borrower under the senior secured term loan. We and each of ENXP LLC’s subsidiaries guarantee the obligations of ENXP LLC under the senior secured term loan. Our obligations under the senior secured term loan are secured by a pledge of our equity interests in ENXP LLC and substantially all of ENXP LLC’s and its subsidiaries’ assets, including a perfected mortgage lien on oil and gas properties that represent at least 80% of the present value in our reserve report. The senior secured term loan bears interest at variable rates, at our option, (x) based on the greater of (a) the London interbank offered rate times the statutory reserves and (b) 1% (in either case the “Adjusted LIBOR”), plus 6.75%, or (y) the greatest of (a) the prime rate, (b) the federal funds effective rate plus  1/2 of 1%, and (c) the Adjusted LIBOR for one month, plus 5.75%. We are required to repay the senior secured term loan quarterly, in the principal amount of $1.9 million, plus accrued and unpaid interest, with the balance due at maturity.

 

We may prepay the senior secured term loan, in whole or in part, at any time subject to an applicable premium (x) in year 1, of 2% of the principal repaid, (i) in year 2, of 1% of the principal repaid, and (ii) on and after the second anniversary of the closing date, no premium. Subject to certain exceptions, we are required to prepay any loans outstanding under the senior secured term loan by an amount equal to: (x) 100% of the net cash proceeds of certain asset dispositions, (y) 50% of the excess cash flow for any fiscal year, subject to reduction to 25% or 0% in the event certain leverage ratios are achieved and (z) 100% of the net cash proceeds of the issuance of unpermitted debt. We and ENXP LLC may also repurchase the senior secured term loan from one or more lenders in the open market or pursuant to Dutch auction procedures, subject to the satisfaction of certain conditions.

 

Subject to certain exceptions and baskets, the agreement governing the senior secured term loan contains customary restrictive covenants, including restrictions on liens, debt, investments, acquisitions, dividends and other

 

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distributions, mergers, consolidations and dispositions. The agreement requires us to meet a maximum leverage ratio of (x) 4.50 to 1.00 for the fiscal quarters ending December 31, 2014 through and including September 30, 2015 and (y) 3.00 to 1.00 for the fiscal quarter ending December 31, 2015 and each fiscal quarter thereafter, tested on a quarterly basis. Additionally, the agreement governing our senior secured term loan requires us to enter into commodity derivative instruments for a minimum of 40% and maximum of 80% of anticipated production from our proved reserves. The agreement provides for customary events of default, subject to applicable grace periods.

 

Liquidity Outlook

 

We expect to incur substantial expenses and generate significant operating losses as we continue to explore and develop our oil and natural gas prospects, and as we opportunistically invest in additional oil and natural gas leases adjacent to our current positions, develop our discoveries which we determine to be commercially viable and incur expenses related to operating as a public company and compliance with regulatory requirements.

 

Our future financial condition and liquidity will be impacted by, among other factors, the success of our exploration and appraisal drilling program, the number of commercially viable oil and natural gas discoveries made and the quantities of oil and natural gas discovered, the speed with which we can bring such discoveries to production, and the actual cost of exploration, appraisal and development of our prospects.

 

We estimate that we will make capital expenditures, excluding the Ft. Trinidad acquisition and capitalized interest and general and administrative expense, of approximately $489 million during the period from January 1, 2014 to December 31, 2015 in order to achieve our plans. We currently intend to finance our future capital expenditures primarily with the net proceeds from the this offering, cash on hand, cash flows provided by operating activities, proceeds from asset divestitures, additional borrowings under our senior secured term loan, if available, and public or private equity or debt financing. We expect the net proceeds from this offering, cash on hand and cash flows provided by operating activities will fully fund our $139 million capital expenditures budget for the period from July 1, 2014 to December 31, 2014 and a substantial portion of our 2015 capital expenditures budget. However, we may require significant additional funds earlier than we currently expect in order to execute our strategy as planned. Additionally, because the wells funded by our 2014 and 2015 drilling plans represent only a small percentage of our potential drilling locations, we will be required to generate or raise significant amounts of additional capital to develop our entire inventory of potential drilling locations if we elect to do so. We may seek additional funding through asset sales, farm-out arrangements and public or private equity or debt financings.

 

Our capital budget may be adjusted as business conditions warrant. The amount, timing and allocation of capital expenditures is largely discretionary and within our control, except that the timing and costs of drilling on our non-operated East Texas stacked play leasehold interests generally will be within the control of the operator. If oil and natural gas prices decline, costs increase significantly, or we are unable to raise additional capital, we could defer a significant portion of our budgeted capital expenditures until later periods to prioritize capital projects that we believe have the highest expected returns and potential to generate near-term cash flows. We routinely monitor and adjust our capital expenditures in response to changes in prices, availability of financing, drilling and acquisition costs, industry conditions, timing of regulatory approvals, availability of rigs, success or lack of success in drilling activities, contractual obligations, internally generated cash flows and other factors both within and outside our control.

 

As of June 30, 2014, on a pro forma basis giving effect to the Pro Forma Transactions described under “Prospectus Summary—Summary Historical and Pro Forma Consolidated Financial Data” and giving further effect to this offering, the use of a portion of the net proceeds of this offering to repay the Chesapeake note in full and the conversion of all outstanding convertible notes into shares of our common stock upon completion of this offering, we would have had outstanding indebtedness of approximately $775 million, consisting of the senior secured term loan, and cash and cash equivalents of approximately $             million.

 

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Cash Flows

 

The discussion of our cash flows and period to period comparisons presented below analyze our historical results as presented in the “Selected Consolidated Financial Data,” which may not be indicative of future results. Cash outflows for undeveloped leasehold acreage that were previously reported as operating outflows in our financial statements when we were an entity engaged in the acquisition and sale of undeveloped oil and natural gas leasehold interests, are reported as investing outflows in the Selected Consolidated Financial Data.

 

The table below sets forth our cash flow data for the years ended December 31, 2011, 2012 and 2013, and the six months ended June 30, 2013 and 2014.

 

     Year Ended
December 31,
    Six Months Ended
June 30,
 
     2011     2012     2013     2013     2014  
                       (unaudited)  
     (in thousands)  

Net cash provided by (used in) operating activities

   $ (1,004   $ (11,072   $ 19,946      $ (596   $ (13,747

Net cash provided by (used in) investing activities

   $ (17,868   $ 12,911      $ (164,482   $ (70,687   $ (41,912

Net cash provided by financing activities

   $ 21,704      $ 2,992      $ 137,877      $ 116,095      $ 54,796   

Opening cash

   $ 2,565      $ 5,397      $ 10,228      $ 10,228      $ 3,569   

Closing cash

   $ 5,397      $ 10,228      $ 3,569      $ 55,040      $ 2,706   

 

Cash flows provided by (used in) operating activities

 

Net cash used in operating activities was $13.7 million for the six months ended June 30, 2014 compared to $0.6 million for the same period in 2013. The increase in cash used between the comparable periods was primarily due to a decrease in cash of $16.4 million related to changes in working capital due to timing of payment of current liabilities, an increase of $5.2 million in cash related general and administrative expenses and an increase of $6.6 million in cash paid for interest expense during the six months ended June 30, 2014 compared to the prior year period. These increases in cash used were partially offset by cash generated by a $14.3 million increase in revenues, net of lease operating expenses and severance taxes, from our oil and natural gas properties.

 

Net cash provided by operating activities was $19.9 million for the year ended December 31, 2013 compared to net cash used in operating activities of $11.1 million for the year ended December 31, 2012. The increase between the comparable periods was primarily due to a $12.2 million increase in revenues, net of lease operating expenses and severance taxes, from our oil and natural gas properties acquired and drilled in 2013 and an increase of $14.9 million related to changes in working capital due to timing on payment and receipt of cash during the year ended December 31, 2013 compared to the prior period. These increases were partially offset by an increase of $17.2 million in cash paid for interest expense.

 

Net cash used in operating activities was $11.1 million for year ended December 31, 2012 compared to net cash used in operating activities of $1.0 million for the year ended December 31, 2011. The increase of $10.1 million was primarily due to an increase in cash general and administrative expenses of $5.5 million, and an increase in interest expense of $3.6 million in 2012, compared to 2011.

 

Cash flows provided by (used in) investing activities

 

Net cash used in investing activities was $41.9 million for the six months ended June 30, 2014 compared to net cash used in investing activities of $70.7 million during the comparable period in 2013. This decrease in net cash used in investing activities is primarily due to a decrease of $69.3 million in acquisitions of oil and gas properties, partially offset by an increase of $40.6 million in oil and natural gas properties additions between the comparable periods. We used approximately $69.3 million for acquisitions of oil and gas properties for the six months ended June 30, 2013 primarily relating to the Chesapeake acquisition.

 

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Net cash used in investing activities was $164.5 million for the year ended December 31, 2013 compared to net cash provided by investing activities of $12.9 million for the year ended December 31, 2012. This decrease in net cash provided by investing activities is primarily due to an increase of $128.9 million in oil and natural gas property additions combined with a decrease of $55.3 million in sales proceeds between the comparable periods. We received net sales proceeds for the year ended December 31, 2013 amounting to $14.3 million from one of our operating partners related to the sale of East Texas stacked play properties, net proceeds of $5.0 million from our sale of our Weld County, Colorado DJ Basin properties and net proceeds of $0.6 million from the sale of interests in two of our producing wells. Sales proceeds during the year ended December 31, 2012 related to proceeds from the disposal of working interests in unevaluated oil and gas properties of $75.2 million.

 

Net cash provided by investing activities was $12.9 million for the year ended December 31, 2012 compared to net cash used in investing activities of $17.9 million for the year ended December 31, 2011. This increase in cash from investing activities of $30.8 million was primarily due to an increase in proceeds from the disposal of oil and gas working interests of $74.0 million, offset by an increase in acquisitions of unevaluated oil and natural gas properties of $30.2 million and additions to evaluated oil and natural gas properties of $6.1 million for the year ended December 31, 2012 compared to the year ended December 31, 2011.

 

Cash flows provided by (used in) financing activities

 

Net cash provided by financing activities was $54.8 million for the six months ended June 30, 2014, compared to net cash provided by financing activities of $116.1 million during the comparable period in 2013. The primary source of cash during the six months ended June 30, 2014 was the issuance of $60 million of our senior unsecured notes, partially offset by debt discounts of $3.0 million and $2.2 million in loan origination costs. For the six months ended June 30, 2013, the primary source of cash was the issuance of $140 million of our senior unsecured notes, partially offset by debt discounts of $4.2 million and loan origination costs of $2.4 million.

 

Net cash provided by financing activities was $137.9 million for the year ended December 31, 2013 compared to net cash provided by financing activities of $3.0 million for year ended December 31, 2012. The primary source of cash during the year ended December 31, 2013 was the issuance of $165.0 million of our senior unsecured notes, partially offset by debt discounts of $5.0 million, $2.0 million in loan origination costs and the payoff of the $17.3 million net outstanding balance of our previously existing Guggenheim credit facility. For the year ended December 31, 2012 the primary source of financing cash was $30.3 million of proceeds from borrowings under the Guggenheim credit facility, net of deposits, offset by payments of $22.5 million of the preexisting senior secured note, $1.3 million of loan origination costs, and $1.7 million of deferred offering costs.

 

Net cash provided by financing activities was $3.0 million for the year ended December 31, 2012 compared to net cash provided by financing activities of $21.7 million for the year ended December 31, 2011. The primary source of cash during the year ended December 31, 2012 was $30.3 million of proceeds of borrowings under the Guggenheim credit facility, net of deposits, offset by payments of $22.5 million of the preexisting note payable, $1.3 million of loan origination costs, and $1.7 million of deferred offering costs. For the year ended December 31, 2011 the primary source of financing cash was proceeds from investment deposits of $12.6 million and proceeds from borrowings net of deposits of $9.3 million.

 

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Obligations and Commitments

 

We had the following contractual obligations and commitments as of June 30, 2014 (in thousands):

 

    Obligations and Commitments Due By Period  
    Total     2014     2015     2016     2017     2018     Thereafter  

Senior unsecured notes(1)

    225,000        —          —          —          —          180,000        45,000   

Subordinated Chesapeake note(2)

    30,798        —          —          —          —          30,798        —     

Interest expense on senior unsecured notes(1)

 

 

151,099

  

 

 

17,081

  

 

 

34,219

  

 

 

34,313

  

 

 

39,496

  

 

 

23,840

  

 

 

2,150

  

Contractual lease payments

    786        233        455        88        10        —          —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total contractual obligations

  $ 407,683      $ 17,314      $ 34,674      $ 34,401      $ 39,506      $ 234,638      $ 47,150   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)   We refinanced and replaced our senior secured notes on July 22, 2014, including a prepayment premium of approximately $52.6 million, with a portion of the net proceeds of our $775 million senior secured term loan and the issuance of $375 million principal amount of our convertible notes.
(2)   Includes approximately $12.8 million of interest paid or to be paid in kind. The principal amount of the Chesapeake note outstanding at June 30, 2014 was approximately $20.3 million. We intend to repay the Chesapeake note in full with the net proceeds of this offering.

 

Critical Accounting Policies and Estimates

 

Our consolidated financial statements are impacted by the accounting policies used and the estimates and assumptions made by management during their preparation. A complete summary of these policies is included in Note 2—Summary of Significant Accounting Policies of the notes to our historical consolidated financial statements. The following is a discussion of our critical accounting policies and estimates.

 

Oil and Natural Gas Properties.    Beginning in the first quarter of 2012, we adopted the full-cost method of accounting for oil and natural gas properties. Accordingly, all costs associated with acquisition, exploration and development of oil and natural gas reserves are capitalized.

 

Under full-cost accounting rules, capitalized costs, less accumulated amortization, and net of deferred income taxes, may not exceed an amount (the ceiling) equal to the sum of: (i) the present value of estimated future net revenues less future production, development, site restoration and abandonment costs derived based on current costs assuming continuation of existing economic conditions and computed using a discount factor of ten percent; (ii) the cost of properties not being amortized; and (iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized. If unamortized costs capitalized within the cost pool exceed the ceiling, the excess is charged to expense and separately disclosed during the period in which the excess occurs. Amounts thus required to be written off are not reinstated for any subsequent increase in the cost center ceiling.

 

Depreciation, depletion and amortization is provided using the unit-of-production method based upon estimates of proved oil and natural gas reserves with oil and natural gas production being converted to a common unit of measure based upon their relative energy content. Investments in unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized. Once the assessment of unproved properties is complete and when major development projects are evaluated, the costs previously excluded from amortization are transferred to the full-cost pool and amortization begins. The full-cost pool also includes estimated future development costs and where significant, dismantlement, restoration and abandonment costs, net of estimated salvage value.

 

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In arriving at depletion rates under the unit-of-production method, the quantities of recoverable oil and natural gas reserves are established based on estimates made by our geologists and engineers, which require significant judgment as does the projection of future production volumes and levels of future costs, including future development costs. In addition, considerable judgment is necessary in determining when unproved properties become impaired and in determining the existence of proved reserves once a well has been drilled. All of these judgments may have significant impact on the calculation of depletion and impairment expense. Sales of proved and unproved properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved oil and natural gas reserves, in which case the gain or loss would be recognized in the statement of operations.

 

Oil and Natural Gas Reserves.    We recorded proved oil and natural gas reserves in the fourth quarter of 2012 and prepared our first third party reserve report as of December 31, 2012. In January 2010, the Financial Accounting Standards Board (“FASB”) issued an update to the oil and natural gas topic, which aligns the oil and natural gas reserve estimation and disclosure requirements with the requirements in the Securities and Exchange Commission (“SEC”) final rule, Modernization of the Oil and Natural Gas Reporting Requirements, which we refer to as the Final Rule. The Final Rule was issued on December 31, 2008 and is intended to provide investors with a more meaningful and comprehensive understanding of oil and natural gas reserves, which should help investors evaluate the relative value of oil and natural gas companies.

 

The Final Rule permits the use of new technologies to determine proved reserve estimates if those technologies have been demonstrated empirically to lead to reliable conclusions about reserve volume estimates.

 

The Final Rule also allows, but does not require, companies to disclose their probable and possible reserves to investors in documents filed with the SEC.

 

In addition, the disclosure requirements require companies to report oil and natural gas reserves using an average price based upon the first of month simple average prices for the prior 12 month period rather than a year-end price. The Final Rule became effective for fiscal years ending on or after December 31, 2009.

 

Reserves and their relation to estimated future net cash flows impact our depletion and impairment calculations. As a result, adjustments to depletion and impairment are made concurrently with changes to reserve estimates. The reserve estimates and the projected cash flows derived from these reserve estimates are prepared in accordance with SEC guidelines. The accuracy of our reserve estimates is a function of many factors including the quality and quantity of available data, the interpretation of that data, the accuracy of various mandated economic assumptions, and the judgments of the individuals preparing the estimates, all of which could deviate significantly from actual results. As such, reserve estimates may vary materially from the ultimate quantities of oil, natural gas, and natural gas liquids eventually recovered.

 

Asset Retirement Obligations.    We comply with Accounting Standards Codification (“ASC”) 410-20, Asset Retirement and Environmental Obligations (“ASC 410-20”), to recognize estimated amounts for asset retirement obligations and asset retirement costs. This standard requires us to record a liability for the fair value of the asset retirement obligations, excluding salvage values. ASC 410-20 requires liability recognition for retirement obligations associated with tangible long-lived assets, such as producing well sites, gathering systems, and related equipment. The obligations included within the scope of ASC 410-20 are those for which we face a legal obligation for settlement. The initial measurement of the asset retirement obligation is fair value, defined as “the price that an entity would have to pay a willing third party of comparable credit standing to assume the liability in a current transaction other than in a forced or liquidation sale.” The significant unobservable inputs to this fair value measurement include estimates of plugging, abandonment, remediation costs, and well life. The inputs are calculated based on historical data as well as current estimates. When the liability is initially recorded, the entity increases the carrying amount of the related long-lived asset. Over time, accretion of the liability is recognized each period, and the capitalized cost is amortized over the useful life of the related asset. Upon

 

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settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement which the entity treats as an adjustment to the full-cost pool

 

Revenue Recognition.    Our oil and natural gas production is currently sold to purchasers by us or by the operator of the property in which we have an interest. We follow the entitlements method of recognizing oil and natural gas revenues and record revenues based on our contractual interest in our properties.

 

Share-Based Compensation.    We follow ASC 718, Compensation—Stock Compensation, which requires the measurement and recognition of compensation expense for all share-based payment awards, including restricted stock units based on estimated grant date fair values. Restricted stock units are valued using the market price of our common share on the date of grant. We record compensation expense, net of estimated forfeitures, over the requisite service period.

 

Use of Estimates.    The preparation of our financial statements requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent assets and liabilities. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and from assumptions used in preparation of our combined financial statements. We provide expanded discussion of our more significant accounting policies, estimates and judgments below. We believe these accounting policies reflect our more significant estimates and assumptions used in preparation of our combined financial statements. See Note 2—Summary of Significant Accounting Policies to our consolidated financial statements for a discussion of additional accounting policies and estimates made by management.

 

Recently Adopted Accounting Standards and Recent Accounting Pronouncements

 

In December 2011 the FASB issued ASU No. 2011-11, Balance Sheet (Topic 210), Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). ASU 2011-11 required entities to disclose both gross information and net information about both instruments and transactions eligible for offset in the statement of financial position and instruments and transactions subject to an agreement similar to a master netting arrangement. In January 2013, an update was issued to further clarify that the disclosure requirements are limited to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (i) offset in the financial statements or (ii) subject to an enforceable master netting arrangement or similar agreement. Adoption of the new guidance, effective for the fiscal year beginning January 1, 2013, had no impact on the Company’s consolidated financial position, results of operations or cash flows. However, we were required to include additional disclosures relating to our derivative instruments.

 

In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). ASU 2014-09 amends the guidance for revenue recognition to replace numerous, industry-specific requirements. The core principle of the amendment is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The amendment implements a five-step process for customer contract revenue recognition that focuses on transfer of control, as opposed to transfer of risk and rewards. The amendment also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers. The amendments are effective for reporting periods beginning after December 15, 2016, and early adoption is prohibited. Entities can transition to the standard either retrospectively to each period presented or as a cumulative-effect adjustment as of the date of adoption. We have not determined the impact the adoption of ASU 2014-09 will have on our consolidated financial statements or the method we will utilize upon adoption during the first quarter of 2017.

 

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No other pronouncements materially affecting our financial statements were issued during 2011, 2012, 2013 or thereafter that have impacted, or are expected to impact, our financial statements and results of operations.

 

Inflation

 

Inflation in the United States has been relatively low in recent years and did not have a material impact on our results of operations for the years ended December 31, 2013, 2012 and 2011. Although the impact of inflation has been insignificant in recent years, it is still a factor in the United States economy, and our industry tends to experience inflationary pressure on the cost of oilfield services and equipment as increasing oil and natural gas prices increase drilling activity.

 

Quantitative and Qualitative Disclosures about Market Risk

 

We are exposed to a variety of market risks including commodity price risk, interest rate risk and counterparty and customer risk. We address these risks through a program of risk management including the use of derivative instruments.

 

Commodity price exposure.    We are exposed to market risk as the prices of oil and natural gas fluctuate as a result of changes in supply and demand and other factors. Due to the inherent volatility in oil and natural gas prices, we have used and may in the future use commodity derivative instruments, such as collars, swaps, puts and basis swaps to mitigate the price risk associated with a significant portion of our anticipated oil and natural gas production. By removing a majority of the price volatility associated with future production, we expect to reduce, but not eliminate, the potential effects of variability in cash flow from operations due to fluctuations in commodity prices. We have entered into and expect to continue to enter into derivative instruments in the future to cover a significant portion of our future production and to comply with covenants in the agreement governing our senior secured term loan.

 

Commodity Derivative Sensitivity Analysis.    Based on oil and natural gas futures prices as of June 30, 2014, and derivative arrangements outstanding as of August 29, 2014 and assuming both a 10% increase and decrease thereon, we would expect to make or receive payments on our oil and natural gas derivative positions as follows (in thousands):

 

     Derivative Contract
Receipt (Payment)
 

Futures prices at June 30, 2014

   $ (1,335)   

Futures prices 10% increase

   $ (4,243)   

Futures prices 10% decrease

   $ 134   

 

For additional information regarding our commodity derivative positions see “—Factors that Significantly Affect Our Results and How We Evaluate Our Operations—Realized Prices on the Sale of Oil and Natural Gas—Commodity Derivative Contracts.”

 

Interest rate risk.    As of June 30, 2014, we had $225 million of senior unsecured notes outstanding, which were subject to floating market rates of interest. On July 22, 2014, we refinanced and replaced our senior secured notes with a portion of the net proceeds of our $775 million senior secured term loan, which bears interest at floating rates, and the issuance of $375 million principal amount of our convertible notes, which bear interest at a fixed rate. See “—Liquidity and Capital Resources—Debt Facilities and Notes.” We may utilize interest rate derivatives to mitigate interest rate exposure to reduce interest rate expenses related to existing debt. Interest rate derivatives are used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio. We had no interest rate derivatives at June 30, 2014.

 

Counterparty and customer credit risk.    We are exposed to counterparty risk from the purchasers of our oil and natural gas, our operating partners, our derivative counterparties and our joint venture partners. Oil and

 

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natural gas and joint interest receivables are generally unsecured. As of June 30, 2014, approximately 87% of our revenues and 81% of accounts receivable were from one purchaser: Shell Trading Company (US).

 

The inability or failure of our significant purchasers, derivative counterparties or partners to meet their obligations or their insolvency or liquidation may adversely affect our financial results.

 

Our derivative instruments expose us to credit risk in the event of nonperformance by counterparties. It is our policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive market makers. We evaluate the credit standing of such counterparties by reviewing their credit rating. The counterparties to our current derivative agreements have investment grade ratings.

 

The inability or failure of our significant purchasers or partners to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results.

 

We maintain cash deposits in certain banks that at times exceeded the maximum insured by the Federal Deposit Insurance Corporation. We monitor the financial condition of the banks and have experienced no losses on these accounts.

 

Off-Balance Sheet Arrangements

 

We do not have any off-balance sheet arrangements.

 

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BUSINESS

 

Overview

 

We are an independent exploration and production company focused on the acquisition, exploration, development and exploitation of conventional and unconventional oil and natural gas resources. As of July 31, 2014 we owned approximately 92,828 net acres in three basins: the East Texas Basin where we are pursuing opportunities in the Lower Cretaceous formations of the Buda, Georgetown, Edwards and Glen Rose (the Buda-Rose play), the Woodbine sandstone and the Eagle Ford shale, which we refer to collectively as the East Texas stacked play; the Permian Basin in West Texas; and the Denver-Julesburg Basin in Wyoming, which we refer to as the DJ Basin. We target liquids-rich resource plays and have built our leasehold acreage position through direct acquisitions from mineral owners and other exploration and production companies. Our management team has extensive engineering, geological, geophysical and technical expertise in our operating areas.

 

Giving pro forma effect to the Ft. Trinidad acquisition, as of June 1, 2014, we had total estimated proved reserves of 41,903 MBoe, 11,405 MBoe of which were developed and 30,499 MBoe of which were undeveloped. See “—Summary Reserve Data.” Pro forma for the Ft. Trinidad acquisition, our average daily net production was approximately 6,016 Boe/day for the three months ended March 31, 2014, approximately 8,363 Boe/day for the three months ended June 30, 2014, and approximately 10,601 Boe/day for the two months ended August 31, 2014.

 

Our primary area of focus is the East Texas stacked play, in which we owned approximately 71,577 net acres as of July 31, 2014. On July 22, 2014, we completed the Ft. Trinidad acquisition, in which we acquired approximately 18,300 net acres in the Ft. Trinidad field in the East Texas stacked play, including interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells waiting on completion as of June 1, 2014, a 3-well salt water disposal system and approximately 30 square miles of 3D seismic, for an initial purchase price of approximately $719 million in cash, subject to additional customary post-closing adjustments. Subsequent to closing, we recognized net negative post-closing adjustments of $26 million, resulting in a cash purchase price of $693 million. The purchase price is subject to additional post-closing adjustments as revenue and expenditures are received and processed. During the period from July 22, 2014 to August 31, 2014, five gross (five net) wells commenced drilling on the Ft. Trinidad acreage. As of August 31, 2014, 13 gross (13 net) wells were waiting on completion on the Ft. Trinidad acreage.

 

We are the operator on approximately 81% of our net acres in the East Texas stacked play. We began drilling on our operated East Texas stacked play acreage in May 2013, and we have drilled or were in the process of drilling 18 gross (18 net) operated wells on this acreage as of June 30, 2014. In addition to our acreage in the East Texas stacked play, as of July 31, 2014 we had approximately 7,089 net acres in the Permian Basin, where we have 100% operated working interests, and 14,162 net acres in the DJ Basin, where we have 100% operated working interests.

 

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The majority of our capital expenditure budget for 2014 through 2016 is focused on the development of our operated acreage in the East Texas stacked play. The following table presents summary data for our acreage in the East Texas stacked play and our other operating areas as of July 31, 2014 and our drilling capital budget of $160 million for the year ending December 31, 2014, $244 million for the year ending December 31, 2015 and $372 million for the year ending December 31, 2016. We also have budgeted estimated capital expenditures of $36 million for the year ending December 31, 2014 and $48 million for each of the years ending December 31, 2015 and 2016 for land acquisition, leasehold extension, seismic surveys and other capital needs. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources” and “—Capital Budget.”

 

          Drilling Capital Budget(1)  
          January 2014—
December 2014
    January 2015—
December 2015
    January 2016—
December 2016
 
    Net Acres     Net Wells     $     Net Wells     $     Net Wells     $  
                (in millions)           (in millions)           (in millions)  

East Texas Stacked Play(2)

             

Horizontal Woodbine

    71,577        6      $ 40        8      $ 52        18      $ 113   

Vertical Buda-Rose

    71,577        38      $ 120        69      $ 192        86      $ 259   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total East Texas Stacked Play

    71,577        44      $ 160        77      $ 244        104      $ 372   

Other(3)

    21,251        —        $ —          —        $ —          —        $ —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total

    92,828        44      $ 160        77      $ 244        104      $ 372   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)   Includes approximately $49 million of drilling capital spent prior to July 1, 2014.
(2)   Operated working interests range from approximately 71% to 100% and non-operated working interests range from approximately 5% to 52%.
(3)   We have 100% operated working interests in the Permian Basin and DJ Basin.

 

Our Operating Areas

 

East Texas Stacked Play

 

As of July 31, 2014, we owned approximately 71,577 net acres in the East Texas stacked play located in Madison, Grimes, Leon, Houston and Walker Counties, Texas. We believe our East Texas stacked play acreage to be prospective for up to 14 zones, including our primary near-term objectives in the Buda-Rose limestone formations of the Buda, Georgetown, Edwards and Glen Rose and the Woodbine sandstone, as well as the Eagle Ford shale. We are currently evaluating the Austin Chalk and Sub Clarksville formations, which may eventually present us with additional drilling locations. We are also utilizing 3D seismic data to evaluate deep gas opportunities in the James Lime, Cotton Valley, Bossier and Haynesville formations.

 

The majority of our leases in the East Texas stacked play not held by production are in the second or third year of their three-year primary term and generally provide for either two- or three-year extension options. In 2014, we plan to drill 44 net wells and have budgeted $160 million for estimated drilling and completion capital expenditures on our acreage in the East Texas stacked play, of which 8 net wells were drilled and $49 million of capital expenditures were made in the first half of 2014. In 2015, we plan to drill 77 net wells and have budgeted $244 million for estimated drilling and completion capital expenditures and in 2016, we plan to drill 104 net wells and have budgeted $372 million for estimated drilling and completion capital expenditures on our acreage in the East Texas stacked play. We anticipate that our drilling plan for 2014 and 2015 combined with acreage already held by production will result in approximately 49,000 of our net acres in the East Texas stacked play being held by production. Substantially all of the acreage acquired in the Ft. Trinidad acquisition is currently held by production.

 

We began drilling on our operated East Texas stacked play acreage in May 2013, and as of June 30, 2014 we have drilled or were in the process of drilling 18 gross (18 net) operated wells on this acreage. 16 gross (16 net) operated wells have been completed and placed in production, while the other two wells were in various stages of drilling or completion. In the Ft. Trinidad acquisition, we acquired interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells awaiting completion as of June 1, 2014. During the period from

 

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July 22, 2014 to August 31, 2014, five gross (five net) wells commenced drilling on the Ft. Trinidad acreage. As of August 31, 2014, 13 gross (13 net) wells were waiting on completion on the Ft. Trinidad acreage. We expect to drill or commence drilling a total of 44 net wells during 2014, including 8 net wells drilled in the first half of 2014.

 

In September 2012, we, together with other operators, contracted with a leading geophysical services company to acquire a 330-square-mile 3D seismic survey covering a majority of our operated and non-operated acreage position in Grimes and Madison Counties and the southern portion of Leon County. Seismic field acquisition activities were completed in October 2013 and interpretation is ongoing. Including the approximately 30-square-mile 3D seismic from the Ft. Trinidad acquisition, we have approximately 360 square miles of 3D seismic data covering our acreage. Recently, there has been significant industry activity in the East Texas stacked play, which, for purposes of industry comparisons, we define as Brazos, Burleson, Grimes, Houston, Leon, Madison, Robertson, and Walker Counties, Texas. The most active operators offsetting our acreage position include EOG Resources, Inc., Halcón Resources Corporation, Anadarko Petroleum Corporation, Cabot Oil & Gas Corporation, Devon Energy Corporation, Apache Corporation, MD America Holdings, LLC, Burk Royalty Company, Silver Oak Energy, LLC, ZaZa Energy Corporation, Contango Oil & Gas Company, Crimson Energy Partners III, L.L.C. and SM Energy Company. According to Drilling Info, Inc. there were 396 drilling permits filed in 2012 and 511 drilling permits filed in 2013 in the East Texas stacked play. According to estimates prepared by Baker Hughes Incorporated, there were 43 rigs operating in the East Texas stacked play as of August 29, 2014.

 

Other Operating Areas

 

Permian Basin

 

As of July 31, 2014, we owned approximately 7,089 net undeveloped acres in the Permian Basin with a 100% operated working interest. Our Permian Basin acreage consists of mostly contiguous acreage in Lynn County, Texas. Initial targets include the interbedded sands in the Upper and Lower Spraberry and the organically-rich carbonates and shales of the Wolfcamp, Dean and Cline intervals. Additional potential targets on our Permian Basin acreage include the Clear Fork, Canyon, Strawn and Mississippian intervals. The majority of our leases in the Permian Basin are in the third year of their three-year primary term and generally provide for two-year extension options. Our drilling capital budget does not include any amounts allocated to develop our Permian Basin acreage in 2014 and 2015.

 

DJ Basin

 

As of July 31, 2014, we owned approximately 14,162 net undeveloped acres in the DJ Basin with a 100% operated working interest. Our DJ Basin acreage is in Laramie and Goshen Counties, Wyoming. Our DJ Basin leasehold acreage is focused on the western, northern and eastern extensions of the Silo Field in Laramie County, Wyoming, and the deepest parts of the basin in Goshen County, Wyoming. We are evaluating several zones within the Niobrara shale, Fort Hays limestone and Codell sand formations. Additional targets include the J Sandstone, Dakota sandstone, Greenhorn limestone and Lyons sandstone formations along with Permian and Pennsylvanian objectives. We believe our DJ Basin leasehold acreage is in areas with a higher incidence of naturally induced faulting and fracturing and moderate to high Niobrara resistivities. The majority of our leases in the DJ Basin are in the third year of their five-year primary term and generally provide for three- to five-year extension options. Our drilling capital budget does not include any amounts allocated to develop our DJ Basin acreage in 2014 and 2015.

 

Our Strategy

 

We intend to actively drill and develop our acreage position in the East Texas stacked play in an effort to maximize its value and resource potential. Through the conversion of our undeveloped acreage, which we believe has significant oil-weighted resource potential, we will seek to increase our production, reserves and cash flow while generating attractive returns on invested capital.

 

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Strategically drill and develop our existing acreage positions.    We plan to strategically drill and develop our East Texas stacked play acreage. In 2013, we drilled or commenced drilling 14 net wells in the East Texas stacked play and began production from 10 net wells. For 2014, we plan to drill 44 net wells and have budgeted $160 million for estimated drilling capital expenditures in our acreage in the East Texas stacked play, including wells drilled and capital expenditures made in the first half of 2014. In 2015, we plan to drill 77 net wells and have budgeted $244 million for estimated drilling capital expenditures on our acreage in the East Texas stacked play. We believe our drilling program will allow us to develop the majority of our undeveloped acreage and to hold a significant portion of our acreage by production.

 

Leverage technology to maximize inventory of high quality drilling prospects.    The majority of our East Texas stacked play acreage is characterized by multiple productive intervals including the Buda-Rose limestone formations of the Buda, Georgetown, Edwards and Glen Rose, the Woodbine sandstone and the Eagle Ford shale. We received data from a 330-square-mile seismic survey from a leading geophysical services company starting in October 2013, and interpretation is ongoing. We also acquired approximately 30 square miles of 3D seismic data in the Ft. Trinidad acquisition. We intend to use this 3D seismic data, micro-seismic data and other advanced technologies for well planning and reservoir characterization, as well as to delineate hazards and locate bypassed pay. Our highly skilled staff of geophysicists and geologists have analyzed over 4,500 well logs in the East Texas stacked play and have extensive experience in using such technologies to optimize completions and resource recovery.

 

Enhance returns through operational efficiencies as our rig count and well count grow.    We intend to focus on the continuous improvement of our operating measures as we seek to convert our undeveloped East Texas stacked play acreage into a cost-efficient development project. We are the operator of approximately 81% of our East Texas stacked play acreage, and our acreage position is generally in large contiguous blocks. This operational control will allow us to more efficiently manage the pace of development activities and the gathering and marketing of our production and control operating costs and technical applications, including horizontal and vertical development. Our operations team will continue to evaluate our operating results against those of other operators in the area in order to benchmark our performance relative to other operators and adopt best practices to decrease drilling times, optimize completions and increase EURs.

 

Selectively acquire additional leasehold acreage in our existing core area.    We have a proven history of acquiring leasehold positions that we believe have substantial oil-weighted resource potential and can meet our targeted returns on invested capital. We plan to continue to leverage the relationships of our experienced land professionals to pursue select additional leasehold acquisitions in the East Texas stacked play that meet our strategic and financial targets.

 

Maintain sufficient liquidity to execute our capital plan.    As of June 30, 2014, giving pro forma effect to the Pro Forma Transactions described under “—Summary Historical and Pro Forma Consolidated Financial Statements,” we had approximately $131.5 million of cash on hand. As of September 9, 2014, we had approximately $102 million of cash on hand. We expect that net proceeds from this offering, cash on hand and cash flows from operations will fully fund our capital expenditure budget for the remainder of 2014 and for 2015. In addition, subject to obtaining the participation of existing or new lenders and other conditions, we may incur additional loans of up to $175 million under our senior secured term loan. We also may pursue dispositions of non-core assets to provide additional drilling capital and liquidity. We intend to actively manage our exposure to commodity price risk through commodity derivative positions on our anticipated future production.

 

Our Strengths

 

We believe we are well positioned to successfully execute our business strategies and achieve our business objectives because of the following competitive strengths:

 

Operating control over the majority of our asset portfolio.    In order to better maintain control over our portfolio, we have established a leasehold position comprised primarily of operated properties. This includes

 

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operating approximately 81% of our East Texas stacked play acreage and 100% of our Permian Basin and DJ Basin acreage positions as of July 31, 2014. As operator, we have primary control over prospect selection and exploration and development timing and capital allocation, as well as the ability to implement logistical practices that we believe will allow us to shorten the time between our drilling and completion operations and first production.

 

Large acreage position in our East Texas stacked play area.    We owned approximately 71,577 net acres in the East Texas stacked play as of July 31, 2014. The majority of our leasehold acreage is in or near areas of considerable activity by large independent operators, although such activity may not be indicative of our future operations. We believe that lease terms on our acreage and our current drilling plan allow us enough time to drill wells that will hold a substantial portion of our acreage by production.

 

Substantial drilling inventory.    We estimate there could be up to 981 net potential drilling locations across our acreage in the East Texas stacked play, including 116 vertical Buda-Rose and 25 horizontal Woodbine proved undeveloped locations, 600 vertical Buda-Rose locations based on 40-acre spacing in core areas and 240 other potential vertical and horizontal locations. During the period from January 1, 2014 through the end of 2015, we anticipate drilling 121 net wells on our East Texas stacked play acreage, leaving us a substantial drilling inventory for future years.

 

Proximity to significant industry infrastructure and access to multiple product markets.    Our acreage in the East Texas stacked play is near substantial existing hydrocarbon gathering, transportation, processing and refining capacity, and has access to multiple product sales points. We believe our East Texas stacked play oil production can generally be sold at a price that is approximately in line with New York Mercantile Exchange-West Texas Intermediate (NYMEX-WTI) benchmark prices due to the East Texas stacked play’s proximity to the Gulf Coast. Consequently, our oil production benefits from higher pricing differentials relative to many North American crude oil producers in other areas, which can often trade at a significant discount to NYMEX-WTI benchmark prices. For example, for the six months ended June 30, 2014, the average realized price for our oil production was $99.15/Bbl compared to an average NYMEX-WTI index price of $100.81/Bbl for the same period.

 

Experienced and incentivized technical, operational and management teams.    Our senior technical team is comprised of geoscience, engineering and operational professionals who average 34 years of industry experience. Members of our technical team have previously held technical and management positions with major and independent oil and natural gas companies, including Anadarko Petroleum Corporation, Mobil Corporation, Exxon Corporation and Encana Corporation. Our core management and operational team has built our existing significant acreage positions in the East Texas stacked play and our other operating areas. We believe that equity ownership is one of the best ways to motivate management and employees. Our management has been and will continue to be compensated with equity incentives.

 

Ft. Trinidad acquisition

 

On July 22, 2014, we completed the acquisition from TreadStone of approximately 18,300 net acres in the Ft. Trinidad field in the East Texas stacked play, including interests in 47 gross (45 net) producing wells and 10 gross (10 net) wells waiting on completion, for an initial purchase price of approximately $719 million in cash, subject to customary post-closing adjustments. Subsequent to closing, we recognized net negative post-closing adjustments of $26 million, resulting in a cash purchase price of $693 million. The purchase price is subject to additional post-closing adjustments as revenue and expenditures are received and processed. We refer to this transaction as the Ft. Trinidad acquisition. The assets acquired from TreadStone include 32,728 Mboe of proved reserves (8,866 Mboe developed) as of June 1, 2014 and estimated production of approximately 9,273 Boe/day for the two months ended August 31. We operate all of the acreage and have an average 89.6% working interest and 83.4% net revenue interest in the acreage acquired in the Ft. Trinidad acquisition. The assets acquired from TreadStone also include a 3-well salt water disposal system currently running at 30% of its total capacity of 66 Mbbl of water per day. Since acquiring the assets in 2012, TreadStone spent approximately $189 million in development capital through June 30, 2014.

 

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The purchase and sale agreement for the Ft. Trinidad acquisition provides for an effective date for the acquisition of April 1, 2014 and includes customary representations and warranties of the parties. The sellers are required to indemnify us for certain losses, including losses resulting from breaches by the sellers of the purchase and sale agreement and the ownership and operation of the acquired leases prior to the effective date. The sellers’ liability for indemnification is subject to individual and aggregate baskets and is capped at 10% of the unadjusted purchase price. We will be required to indemnify the sellers for certain losses, including losses resulting from breaches by us of the purchase and sale agreement and the ownership and operation of the acquired leases after the effective date.

 

Chesapeake Acquisition

 

In April 2013, we acquired 57,275 net acres in the East Texas stacked play from affiliates of Chesapeake Energy Corporation and certain co-owners, which we refer to as the Chesapeake acquisition, including nine producing wells, one well awaiting a pipeline connection and one non-producing well, for approximately $93 million, consisting of approximately $75 million in cash and a subordinated promissory note in the original principal amount of $18 million, which we refer to as the Chesapeake note. We generally have a 100% working interest in the acreage acquired in the Chesapeake acquisition, and we will operate all of the acreage acquired unless we enter into subsequent joint operating agreements with other operators.

 

Our Operations

 

Acreage

 

The following table sets forth certain information regarding our undeveloped and developed acreage in the East Texas stacked play and our other operating areas as of July 31, 2014. Acreage related to royalty, overriding royalty and other similar interests is excluded from this summary.

 

    

 

Undeveloped Acres

     Developed Acres      Total      % of
Acreage
Held by

Production
 
     Gross      Net      Gross      Net      Gross      Net     

Operated East Texas stacked play

     30,835         29,483         33,080         28,514         63,915         57,997         49

Non-operated East Texas stacked play

     50,310         12,500         4,592         1,080         54,902         13,580         8
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total East Texas stacked play

     81,145         41,983         37,672         29,594         118,817         71,577         41

Other

     21,251         21,251         —           —           21,251         21,251         0
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total(1)

     102,396         63,234         37,672         29,594         140,068         92,828         32
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)   Certain totals may not add due to rounding.

 

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Undeveloped acreage expirations

 

The following table sets forth the number of gross and net undeveloped acres in the East Texas stacked play and our other operating areas as of July 31, 2014 that will expire in the periods indicated unless production is established within the spacing units covering the acreage prior to the expiration dates. The table assumes we exercise all available lease extension options. We anticipate that our budgeted drilling program will hold by production many leases that would otherwise expire or require payment of lease extension options. Of the 26 undeveloped drilling locations included in our reserve report dated June 1, 2014, 22 are located on developed acreage and should not be subject to any potential lease expirations. All of the acreage acquired in the Ft. Trinidad acquisition is currently held by production.

 

    2014     2015     2016     2017+  
    Gross     Net     Gross     Net     Gross     Net     Gross     Net  

Operated East Texas stacked play

    5,980        5,908        13,787        12,708        7,181        7,181        3,887        3,686   

Non-operated East Texas stacked play

    65        15        5,919        1,467        12,363        3,140        31,963        7,878   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total East Texas stacked play

    6,045        5,923        19,706        14,175        19,544        10,321        35,850        11,564   

Other

    —          —          2,731        2,731        5,682        5,682        12,838        12,838   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total(1)

    6,045        5,923        22,437        16,906        25,226        16,003        48,688        24,402   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)   Certain totals may not add due to rounding.

 

Many of the leases comprising the acreage set forth in the table above will expire at the end of their respective primary terms unless production from the leasehold acreage has been established prior to such date, in which event the lease will remain in effect until the cessation of production in commercial quantities. While we may attempt to secure a new lease upon the expiration of certain of our acreage, there are some third-party leases that may become effective immediately if our leases expire at the end of their respective terms and production has not been established prior to such date. We have options to extend many of our leases through payment of additional lease bonus payments prior to the expiration of the primary term of the leases, and the table above assumes that we exercise those options. Our leases are mainly fee leases with three to five years of primary term.

 

Productive wells and drilling activity

 

The following table presents our total gross and net productive wells in the East Texas stacked play and our other operating areas by oil or natural gas completion as of June 30, 2014 without giving effect to the Ft. Trinidad acquisition:

 

     Gross Productive Wells      Net Productive Wells         
     Oil      Natural
Gas
     Total      Oil      Natural
Gas
     Total      % Operated  

East Texas stacked play

     27.0         6.0         33.0         21.5         5.1         26.6         94

Other

     —           —           —           —           —           —        
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total

     27.0         6.0         33.0         21.5         5.1         26.6         94
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

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The following table presents our total gross and net productive wells in the East Texas stacked play and our other operating areas by oil or natural gas completion as of December 31, 2013 without giving effect to the Ft. Trinidad acquisition:

 

     Gross Productive Wells      Net Productive Wells         
     Oil      Natural
Gas
     Total      Oil      Natural
Gas
     Total      % Operated  

East Texas stacked play

     20.0         6.0         26.0         14.5         5.1         19.6         92

Other

     —           —           —           —           —           —           —     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total

     20.0         6.0         26.0         14.5         5.1         19.6         92
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

Gross wells” represents the number of wells in which a working interest is owned, and “net wells” represents the total of our fractional working interests owned in gross wells.

 

The following table summarizes our drilling activity for the years ended December 31, 2012 and 2013 and the six months ended June 30 , 2014. We did not drill any development wells during 2012 or 2013 and did not participate in the drilling of any wells during 2011.

 

     Year Ended
December 31,
2012
     Year Ended
December 31,
2013
     Six Months
Ended
June 30, 2014
 
     Gross      Net      Gross      Net      Gross      Net  

Exploratory Wells

                 

Productive

     3         0.3         14         10.1         4         4.0   

Dry

     1         0.3         2         0.4         —           —     

Development Wells

                 

Productive

     —           —           —           —           3         2.9   

Dry

     —           —           —           —           —           —     

Total Wells

                 

Productive

     3         0.3         14         10.1         7         6.9   

Dry

     1         0.3         2         0.4         —           —     
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Total

     4         0.6         16         10.5         7         6.9   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

As of June 30, 2014, we had 2 gross (2 net) operated wells in various stages of drilling or completion. Subsequent to June 30, 2014, we began production on one of the operated wells referred to above.

 

Estimated proved reserves

 

The summary data presented below with respect to our estimated proved reserves as of December 31, 2012, December 31, 2013 and June 1, 2014 and with respect to estimated proved reserves attributable to the properties acquired in the Ft. Trinidad acquisition as of June 1, 2014 have been prepared by Cawley, Gillespie & Associates, Inc., our independent reserve engineering firm, in accordance with rules and regulations of the SEC applicable to companies involved in oil and natural gas producing activities.

 

All of the undeveloped locations in our reserves report dated December 31, 2013 and June 1, 2014 are expected to be developed within five years of their initial disclosure as proved undeveloped reserves.

 

For a discussion of some of the risks associated with estimating reserves, see “Risk Factors—Risks Related to the Oil and Natural Gas Industry and Our Business—Our estimated proved reserves are based on many assumptions that may turn out to be inaccurate. Any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves.”

 

As of December 31, 2012, 2013 and June 1, 2014, all of our reserves were owned by our wholly owned subsidiary, ENXP LLC.

 

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The table below summarizes for the East Texas stacked play and our other operating areas, our estimated proved reserves as of December 31, 2012 and 2013 and June 1, 2014, the estimated proved reserves attributable to the properties acquired in the Ft. Trinidad acquisition as of June 1, 2014, and our estimated proved reserves as of June 1, 2014 giving pro forma effect to the Ft. Trinidad acquisition. We had no proved undeveloped reserves as of December 31, 2012.

 

     As of
December 31,
    As of
June 1,
    Ft. Trinidad
Acquisition
as of
June 1,
    Pro Forma
as of
June 1,
 
       2012(1)       2013(1)     2014(1)     2014(2)     2014  

Proved reserves:

          

East Texas stacked play

          

Oil (MBbl)

     18        5,859        7,484        25,277        32,761   

Natural gas (MMcf)(3)

     31        7,188        5,610        22,492        28,102   

Natural gas liquids (MBbl)

     —          —          757        3,702        4,458   

Equivalent (MBoe)

     24        7,057        9,175        32,728        41,903   

DJ Basin(4)

          

Oil (MBbl)

     5        —          —         

Natural gas (MMcf)

     18        —          —         

Equivalent (MBoe)

     8        —          —         
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total equivalent (MBoe)

     32        7,057        9,175        32,728        41,903   
  

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Proved developed reserves:

          

Oil (MBbl)

     23        1,947        1,898        6,754        8,652   

Natural gas (MMcf)(3)

     49        2,897        2,302        6,321        8,623   

Natural gas liquids (MBbl)

     —          —          257        1,059        1,316   

Equivalent (MBoe)

     32        2,430        2,538        8,866        11,405   

Proved undeveloped reserves(5)(6):

          

Oil (MBbl)

     —          3,912        5,585        18,524        24,109   

Natural gas (MMcf)(3)

     —          4,292        3,308        16,171        19,479   

Natural gas liquids (MBbl)

     —          —          500        2,643        3,143   

Equivalent (MBoe)

     —          4,627        6,637        23,862        30,499   

Total proved developed reserves as a percent of total proved reserves

     100     34     28     27     27

Oil as a percent of total proved reserves

     72     83     82     77     78

PV-10 (in thousands)(7)

   $ 875      $ 149,045      $ 205,719      $ 1,208,044      $ 1,413,763   

Proved developed PV-10 as a percent of total PV-10

     100     60     43     33     34

 

(1)   Our estimated proved reserves were determined using index prices for oil and natural gas without giving effect to derivative transactions, and were held constant throughout the life of the properties. The unweighted arithmetic average first-day-of-the-month prices for the twelve months ended June 1, 2014, for the twelve months ended December 31, 2013 and for the twelve months ended December 31, 2012 were $99.38/Bbl, $96.94/Bbl and $94.71/Bbl for oil respectively, and $4.07/MMBtu, $3.67/MMBtu, and $2.75/MMBtu for natural gas, respectively. These prices were adjusted by well for gravity, quality, heating value, shrinkage, transportation and marketing. Including such adjustments, the prices as of June 1, 2014, December 31, 2013 and December 31, 2012 were $99.12/Bbl, $95.16/Bbl and $91.68/Bbl for oil, respectively, $3.76/Mcf, $3.39/Mcf and $3.34/Mcf for natural gas, respectively and $28.22/Bbl for natural gas liquids as of June 1, 2014.
(2)  

Ft. Trinidad acquisition proved reserves were determined using the same index prices indicated above and the same adjustment procedure. Including such adjustments, the prices as of June 1, 2014 were $102.09/Bbl for oil, $4.53/Mcf for natural gas and $45.42/Bbl for natural gas liquids. Oil production from the properties

 

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acquired in the Ft. Trinidad acquisition benefited from favorable pricing in 2013, resulting in a higher average crude oil price differential than our other properties. Natural gas production from the properties acquired in the Ft. Trinidad acquisition benefited from materially different purchase contracts still in effect, transportation, heating value, and plant recoveries, resulting in a higher natural gas price differential than our other properties.

(3)   Includes immaterial amounts of natural gas liquids at December 31, 2012 and 2013.
(4)   Consists of reserves attributable to DJ Basin assets located in Weld County, Colorado, which we sold in June 2013.
(5)   As of June 1, 2014 includes 26 gross (25.5 net) proved undeveloped drilling locations in which we have an average working interest of 98.0% and an average net revenue interest of 76.5% and assumes average estimated drilling and completion costs of $6.1 million per well for us as of June 1, 2014. The Ft. Trinidad acquisition proved undeveloped net Mboe value as of June 1, 2014 includes 116 gross (105 net) vertical Buda-Rose locations with 22,602 Mboe, an average working interest of 90.4% and an average net revenue interest of 83.3% and average estimated drilling and completion costs of $2.6 million per well, as well as 29 gross (29 net) vertical Edwards locations.
(6)   We did not have any proved undeveloped reserves on December 31, 2012. During 2013, our proved undeveloped reserves increased by 4,627 Mboe due to discoveries from our participation in the drilling of 14 gross (10 net) productive wells during 2013. The Chesapeake acquisition in 2013 included proved developed reserves but did not include any proved undeveloped reserves.
(7)   PV-10 is a non-GAAP financial measure and is derived from Standardized Measure, which is the most directly comparable GAAP financial measure. PV-10 is equal to the Standardized Measure of discounted future net cash flows at the applicable date, before deducting future income taxes, discounted at 10%. We believe that the presentation of PV-10 is relevant and useful to investors because it presents the relative monetary significance of our properties regardless of tax structure. Further, investors may utilize the measure as a basis for comparison of the relative size and value of our proved reserves to other companies. We use this measure when assessing the potential return on investment related to our oil and natural gas properties. However, PV-10 is not equal to, nor a substitute for, the Standardized Measure of discounted future net cash flows. Our PV-10 and the Standardized Measure of discounted future net cash flows do not purport to present the fair value of our proved reserves. See “—Reconciliation of PV-10 to Standardized Measure” below.

 

Reconciliation of PV-10 to Standardized Measure

 

Standardized Measure represents the present value of estimated future cash inflows from proved reserves, less future development, production and income tax expenses, discounted at 10% per annum to reflect timing of future cash flows.

 

The following table provides a reconciliation of PV-10 to the GAAP financial measure of Standardized Measure as of December 31, 2013 and 2012. We have not provided a reconciliation of PV-10 to the Standardized Measure as of June 1, 2014 as we have not prepared a Standardized Measure as of June 1, 2014:

 

     At December 31,  
           2012                 2013        
     (unaudited) ($ thousands)  

Present value of estimated future net revenues (PV-10)

   $ 875      $ 149,045   

Future income taxes, discounted at 10%

   $ (237   $ (35,159
  

 

 

   

 

 

 

Standardized measure of discounted future net cash flows

   $ 638      $ 113,886   
  

 

 

   

 

 

 

 

There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting the future rates of production and timing of development expenditures. Reserve data represent estimates only and should not be construed as being exact.

 

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Preparation of reserves estimates and internal controls over reserve estimation process

 

Our estimated reserves at December 31, 2012, December 31, 2013 and June 1, 2014 and the estimated reserves attributable to the properties acquired in the Ft. Trinidad acquisition at June 1, 2014 were prepared by Cawley, Gillespie and Associates, Inc., or Cawley, Gillespie, our independent reserve engineers. No director, officer or key employee of Cawley, Gillespie has any financial ownership in us. Cawley, Gillespie’s compensation for the required investigations and preparation of its reports is not contingent upon the results obtained and reported.

 

Our internal professional staff works closely with Cawley, Gillespie to ensure the integrity, accuracy and timeliness of data that is furnished to them for their reserve estimation process. All of the reserve information maintained in our secure reserve engineering database is provided to the external engineers. In addition, we provide Cawley, Gillespie other pertinent data, such as seismic information, geologic maps, well logs, production tests, well performance data, operating procedures and relevant economic criteria. We make all requested information, as well as our pertinent personnel, available to the external engineers as part of their evaluation of our reserves. We expect to have our reserve estimates prepared by independent third-party reserve engineers at least annually.

 

John Richards is the technical person responsible for overseeing the preparation of our reserve estimates. Mr. Richards has over 35 years of industry experience with positions of increasing responsibility in engineering, operations and management with companies such as Union Pacific Resources, Anadarko Petroleum and EnCana Oil & Gas. He holds a Bachelor of Science Degree in Mechanical Engineering from Louisiana Tech University.

 

The independent engineering analysis presented in the Cawley, Gillespie reports was overseen by Kenneth J. Mueller. Mr. Mueller is an experienced reservoir engineer having been a practicing petroleum engineer since 1979. He has more than 34 years of experience in reserve evaluation. He has a Bachelor of Science degree in Petroleum Engineering from Texas A&M University. Mr. Mueller is a licensed Professional Engineer in the State of Texas and is an active member of the Society of Petroleum Engineers and the Texas Society of Professional Engineers.

 

Technology used to establish proved reserves

 

Under SEC rules, proved reserves are those quantities of oil and natural gas that by analysis of geoscience and engineering data can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs, and under existing economic conditions, operating methods and government regulations. The term “reasonable certainty” implies a high degree of confidence that the quantities of oil and natural gas actually recovered will equal or exceed the estimate. Reasonable certainty can be established using techniques that have been proven effective by actual production from projects in the same reservoir or an analogous reservoir or by other evidence using reliable technology that establishes reasonable certainty. Reliable technology is a grouping of one or more technologies (including computational methods) that has been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation.

 

To establish reasonable certainty with respect to our estimated proved reserves, Cawley, Gillespie employed technologies that have been demonstrated to yield results with consistency and repeatability. The technologies and economic data used in the estimation of our reserves include, but are not limited to, electrical logs, radioactivity logs, core analyses, geologic maps and available downhole and production data, seismic data and well test data. Reserves attributable to producing wells with sufficient production history were estimated using appropriate decline curves or other performance relationships. Reserves attributable to producing wells with limited production history were estimated using performance from analogous wells in the surrounding area and geologic data to assess the reservoir continuity. These wells were considered to be analogous based on production performance from the same formation and completion using similar techniques.

 

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Production, price and cost history

 

Oil and natural gas are commodities. The price that we receive for the oil and natural gas we produce is largely a function of market supply and demand. Demand for oil and natural gas in the United States has increased during the last decade with periods of volatility. Demand is impacted by general economic conditions, weather and other seasonal conditions. Over or under supply of oil or natural gas can result in substantial price volatility. Historically, commodity prices have been volatile, and we expect that volatility to continue in the future. A substantial or extended decline in oil or natural gas prices or poor drilling results could have a material adverse effect on our financial position, results of operations, cash flows, quantities of oil and natural gas reserves that may be economically produced, and our ability to access capital markets.

 

The following table sets forth summary data with respect to our production results, average sales price and production costs on a historical basis for the six months ended June 30, 2014.

 

     East Texas
Stacked Play
     DJ Basin(3)      Total  

Net production volumes:

        

Oil (Bbl)

     201,771         —           201,771   

Natural gas liquids (Bbl)

     23,172         —           23,172   

Natural gas (Mcf)

     139,570         —           139,570   

Total (Boe)

     248,205         —           248,205   

Average daily production volumes:

        

Oil (Bbl)

     1,114.8         —           1,114.8   

Natural gas liquids (Bbl)

     128.0         —           128.0   

Natural gas (Mcf)

     771.1         —           771.1   

Total (Boe)

     1,371.3         —           1,371.3   

Average prices:

        

Oil (Bbl)

   $ 99.15         —         $ 99.15   

Natural gas liquids (Bbl)

   $ 31.22         —         $ 31.22   

Natural gas (Mcf)

   $ 3.71         —         $ 3.71   

Total (Boe)

   $ 85.61         —         $ 85.61   

Operating costs and expenses (per Boe):

        

Lease operating expenses

   $ 17.71         —         $ 17.71   

Production and ad valorem taxes

   $ 4.24         —         $ 4.24   

Depreciation, depletion and amortization(1)(2)

     n/a         —         $ 37.51   

General and administrative expenses(2)

     n/a         —         $ 35.55   

 

(1)   We utilize the full cost method of accounting for our oil and natural gas proprieties. Under this method, depreciation, depletion and amortization (DD&A) is calculated at the country level rather than the field level.
(2)   During the six months ended June 30, 2014, we did not allocate DD&A and general and administrative expenses to the field level.
(3)   Our producing DJ Basin assets were sold during June 2013.

 

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The following table sets forth summary data with respect to our production results, average sales prices and production costs on a historical basis for the year ended December 31, 2013.

 

     East Texas
Stacked Play
     DJ
Basin
     Total  

Net production volumes:

        

Oil (Bbl)

     161,260         319         161,579   

Natural gas liquids (Bbl)

     5,014         109         5,123   

Natural gas (Mcf)

     127,874         729         128,603   

Total (Boe)

     187,586         550         188,136   

Average daily production volumes:

        

Oil (Bbl)

     441.8         0.9         442.7   

Natural gas liquids (Bbl)

     13.7         0.3         14.0   

Natural gas (Mcf)

     350.3         2.0         352.3   

Total (Boe)

     513.9         1.5         515.4   

Average prices:

        

Oil (Bbl)

   $ 98.04       $ 86.85       $ 98.02   

Natural gas liquids (Bbl)

   $ 25.96       $ 28.84       $ 26.02   

Natural gas (Mcf)

   $ 3.63       $ 3.28       $ 3.62   

Total (Boe)

   $ 87.45       $ 60.46       $ 87.37   

Operating costs and expenses (per Boe):

        

Lease operating expenses

   $ 17.10       $ 12.03       $ 17.09   

Production and ad valorem taxes

   $ 4.63       $ 4.03       $ 4.60   

Depreciation, depletion and amortization(1)(2)

     n/a         n/a       $ 35.39   

General and administrative expenses(2)

     n/a         n/a       $ 89.76   

 

(1)   We utilize the full cost method of accounting for our oil and natural gas proprieties. Under this method, depreciation, depletion and amortization (DD&A) is calculated at the country level rather than the field level.
(2)   During the year ended December 31, 2013, we did not allocate DD&A and general and administrative expenses to the field level.

 

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The following table sets forth summary data with respect to our production results, average sales prices and production costs on a historical basis for the year ended December 31, 2012.

 

     East Texas
Stacked Play
     DJ
Basin
     Total  

Net production volumes:

        

Oil (Bbl)

     347         1,900         2,247   

Natural gas liquids (Bbl)

     —           384         384   

Natural gas (Mcf)

     —           3,903         3,903   

Total (Boe)

     347         2,934         3,281   

Average daily production volumes:

        

Oil (Bbl)

     0.9         5.2         6.1   

Natural gas liquids (Bbl)

     —           1.0         1.0   

Natural gas (Mcf)

     —           10.7         10.7   

Total (Boe)

     0.9         8.1         9.0   

Average prices:

        

Oil (Bbl)

   $ 87.69       $ 87.54       $ 87.58   

Natural gas liquids (Bbl)

   $ —         $ 27.75       $ 27.75   

Natural gas (Mcf)

   $ —         $ 2.17       $ 2.17   

Total (Boe)

   $ 87.69       $ 63.21       $ 65.80   

Operating costs and expenses (per Boe):

        

Lease operating expenses

   $ 2.91       $ 0.58       $ 3.49   

Production and ad valorem taxes

   $ 0.43       $ 3.79       $ 4.22   

Depreciation, depletion and amortization(1)(2)

     n/a         n/a       $ 93.49   

General and administrative expenses(2)

     n/a         n/a       $ 3,212   

 

(1)   We utilize the full cost method of accounting for our oil and natural gas proprieties. Under this method, depreciation, depletion and amortization (DD&A) is calculated at the country level rather than the field.
(2)   During the year ended December 31, 2012, we did not allocate DD&A and general and administrative expenses to the field level.

 

Capital Budget

 

We have targeted a majority of our estimated capital expenditures for 2014 and 2015 for drilling and completion in the East Texas stacked play. The following table presents our estimated capital expenditures, excluding capitalized interest and general and administrative expense, for drilling and completion, land acquisition, leasehold extension and seismic surveys for 2014 and 2015 in the East Texas stacked play. We currently do not plan any capital expenditures in 2014 or 2015 for our other operating areas.

 

     Capital Expenditure Budget
January 2014—December 2014(1)
     Capital Expenditure Budget
January 2015—December 2015(1)
 
             Net Wells                       $                      Net Wells                       $          

Drilling & Completion:

           

East Texas stacked play

     44       $ 160         77       $ 244   
  

 

 

    

 

 

    

 

 

    

 

 

 

Drilling & Completion Total

     44       $ 160         77       $ 244   

Other:

           

East Texas stacked play

     —         $ 36         —         $ 48   
  

 

 

    

 

 

    

 

 

    

 

 

 

Other Total

     —         $ 36         —         $ 48   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total

     44       $ 196         77       $ 292   
  

 

 

    

 

 

    

 

 

    

 

 

 

 

(1)   Includes approximately $49 million of drilling capital and approximately $8 million of other capital spent prior to July 1, 2014.

 

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The ultimate amount of capital we will expend is largely discretionary and may fluctuate materially based on market conditions, the success of drilling operations, access to capital and other factors. Additionally, the timing and costs of drilling on our non-operated East Texas stacked play leasehold acreage generally will be within the control of the operator. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.”

 

Title to Properties

 

As is customary in the oil and natural gas industry, we initially conduct a preliminary review of the title to our properties. Prior to the commencement of drilling operations on those properties, we will conduct a thorough title examination and perform curative work with respect to significant defects. To the extent title opinions or other investigations reflect title defects on those properties, we will typically be responsible for curing any title defects at our expense. We will not commence drilling operations on a property until we have cured any material title defects on such property. We will obtain title opinions on substantially all of our producing properties and expect to have satisfactory title to our producing properties in accordance with standards generally accepted in the oil and natural gas industry. Prior to completing an acquisition of producing oil and natural gas leases, we will perform title reviews on the most significant leases, and, depending on the materiality of the properties, we may obtain a title opinion or review previously obtained title opinions. Our oil and natural gas properties are subject to customary royalty and other interests, liens to secure borrowings under the senior secured term loan, liens for current taxes, and other burdens that we believe do not materially interfere with the use or affect our carrying value of the properties. See “Risk Factors—Risks Related to the Oil and Natural Gas Industry and Our Business—We may incur losses as a result of title defects in the properties in which we invest.”

 

Oil and Natural Gas Leases

 

The typical oil and natural gas lease agreement covering our properties provides for the payment of royalties to the mineral owner for all oil and natural gas produced from any wells drilled on the leased premises. The lessor royalties and other leasehold burdens on our properties in Texas are generally 25.0% or less, resulting in a net revenue interest to us generally of at least 75% or more. Royalties and other leasehold burdens on our properties in Wyoming are 20%, resulting in a net revenue interest to us of 80%.

 

Competition

 

The oil and natural gas industry is highly competitive in all phases. We encounter competition from other oil and natural gas companies in all areas of operation, from the acquisition of leasing options on oil and natural gas properties to the exploration and development of those properties. Our competitors include major integrated oil and natural gas companies, numerous independent oil and natural gas companies, individuals and drilling and income programs. Many of our competitors are large, well established companies that have substantially larger operating staffs and greater capital resources than we do. Such companies may be able to pay more for lease options on oil and natural gas properties and exploratory locations and to define, evaluate, bid for and purchase a greater number of properties and locations than our financial or human resources permit. Our ability to acquire additional properties and to discover reserves in the future will depend upon our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment. See “Risk Factors—Risks Related to the Oil and Natural Gas Industry and Our Business—Competition in the oil and natural gas industry is intense, making it more difficult for us to acquire properties, market oil and natural gas and secure trained personnel.”

 

Hydraulic Fracturing

 

We will use hydraulic fracturing as a means to enhance the productivity of substantially all wells that we drill and complete. Hydraulic fracturing is a necessary part of the completion process because our properties are dependent upon our ability to effectively fracture the producing formations in order to produce at economic rates.

 

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We have and continue to follow applicable industry standard practices and legal requirements for groundwater protection in our operations that are subject to supervision by state and federal regulators (including the Bureau of Land Management on federal acreage). These protective measures include setting surface casing at a depth sufficient to protect fresh water zones as determined by regulatory agencies, and cementing the well to create a permanent isolating barrier between the casing pipe and surrounding geological formations. For recompletions of existing wells, the production casing is pressure tested prior to perforating the new completion interval.

 

Injection rates and pressures are monitored instantaneously and in real time at the surface during our hydraulic fracturing operations. Pressure is monitored on both the injection string and the immediate annulus to the injection string. Hydraulic fracturing operations would be shut down immediately if an abrupt change occurred to the injection pressure or annular pressure.

 

Certain state regulations require disclosure of the components in the solutions used in hydraulic fracturing operations, subject in some instances to exemptions for the disclosure of trade secrets. Approximately 99% of the hydraulic fracturing fluids we expect to use are made up of water and sand. The remainder of the constituents in the fracturing fluid are managed and used in accordance with applicable requirements.

 

Hydraulic fracture stimulation requires the use of a significant volume of water. Upon flowback of the water, we intend to dispose of it in a way that minimizes the impact to nearby surface water by disposing into approved disposal or injection wells. We do not intend to discharge wastewater to the surface.

 

For information regarding existing and proposed governmental regulations regarding hydraulic fracturing and related environmental matters, please read “—Regulation of the Oil and Natural Gas Industry—Environmental, Health and Safety Regulation.” For related risks to our stockholders, please read “Risk Factors—Risks Related to the Oil and Natural Gas Industry and Our Business—Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.”

 

Regulation of the Oil and Natural Gas Industry

 

Our operations are substantially affected by federal, state and local laws and regulations. In particular, oil and natural gas production and related operations are, or have been, subject to price controls, taxes and numerous other laws and regulations. All of the jurisdictions in which we own or operate properties for oil and natural gas production have statutory provisions regulating the exploration for and production of oil and natural gas, including provisions related to permits for the drilling of wells, bonding requirements to drill or operate wells, the location of wells, the method of drilling and casing wells, the surface use and restoration of properties upon which wells are drilled, sourcing and disposal of water used in the drilling and completion process, and the abandonment of wells. Our operations are also subject to various conservation laws and regulations. These include regulation of the size of drilling and spacing units or proration units, the number of wells which may be drilled in an area, and the unitization or pooling of oil and natural gas wells, as well as regulations that generally prohibit the venting or flaring of natural gas and impose certain requirements regarding the ratability or fair apportionment of production from fields and individual wells.

 

Failure to comply with applicable laws and regulations could result in substantial penalties. The regulatory burden on the industry increases the cost of doing business and affects profitability. Although we believe we are in material compliance with all applicable laws and regulations, and that such continued compliance with existing requirements will not have a material adverse effect on our financial position, cash flows or results of operations, such laws and regulations could be, and are frequently are, amended or reinterpreted. Additionally, currently unforeseen environmental incidents may occur or past non-compliance with environmental laws or regulations may be discovered. Therefore, we are unable to predict the future costs or impact of compliance or

 

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non-compliance. Additional proposals and proceedings that affect the oil and natural gas industry are regularly considered by Congress, the states, the Federal Energy Regulatory Commission, or FERC, and the courts. We cannot predict when or whether any such proposals may become effective.

 

Regulation of Transportation of Oil

 

Sales of crude oil, condensate and natural gas liquids are not currently regulated and are made at negotiated prices. Nevertheless, Congress could reenact price controls or impose other regulatory requirements in the future.

 

Our sales of crude oil are affected by the availability, terms and cost of transportation. The transportation of oil in common carrier pipelines is also subject to rate and access regulation. FERC regulates interstate oil (including NGLs) pipeline transportation service and rates under the Interstate Commerce Act. Historically, interstate oil pipeline rates were required to be cost-based. Currently, rates are generally adjusted by reference to an index, although shippers may challenge these adjustments, and pipelines may seek adjustments in excess of the index.

 

Rates may be cost-based, and settlement rates agreed to by all shippers are permitted. In addition, market based rates are permitted in circumstances where a pipeline demonstrates a lack of market power in a given geographical area before FERC. Effective January 1, 1995, FERC implemented regulations establishing an indexing system (based on the Producer Price Index (PPI), plus or minus a value set by FERC) for transportation rates for oil that allows for an annual increase or decrease in such index-based transportation rates. FERC re-evaluates the currently applicable index for setting such index-based rates every five years. The most recent review resulted in an increase of the index, and thus allows pipelines to increase rates annually by PPI + 2.65%, a larger percentage in addition to PPI for the five year period ending in July 2016 than had previously been in effect (which was PPI + 1.3%). This most recent index adjustment is currently being challenged by oil pipeline shippers in Federal court, and if successful this challenge could result in a decrease in the currently applicable index for annual adjustment of oil pipeline rates, although this is by no means certain or likely. FERC recently has adopted one change, and proposed others, to its rules governing the reporting of pipeline revenues and costs, with the stated aim of improving the transparency of the inputs to pipeline rates. It is not clear at this time whether the recent and potential changes to FERC’s rules will result in increased challenges to pipeline rates or stricter FERC scrutiny of such rates.

 

Intrastate oil pipeline transportation rates typically are subject to regulation by state regulatory commissions. The basis for intrastate oil pipeline regulation, and the degree of regulatory oversight and scrutiny given to intrastate oil pipeline rates, varies from state to state. Insofar as effective interstate and intrastate rates are equally applicable to all comparable shippers, we believe that the regulation of oil transportation rates will not affect our operations in any way that is of material difference from those of our competitors who are similarly situated.

 

Further, interstate and intrastate common carrier oil pipelines must provide service on a non-discriminatory basis. Under this common carrier standard, common carriers must offer service to all similarly situated shippers requesting service on the same terms and under the same rates. When oil pipelines operate at full capacity, access is governed by prorationing provisions set forth in the pipelines’ published tariffs. Often the priority of a given shipper in the event of prorationing is dependent upon its history of shipping on a particular pipeline, with higher priority, and thus more capacity, allocated to relatively long standing shippers over new shippers. However, as a general matter, FERC does not have jurisdiction to prevent a common carrier oil pipeline from abandoning all or part of its services. Accordingly, we believe that access to oil pipeline transportation services generally will be available to us to the same extent as to our similarly situated competitors on a given pipeline.

 

Regulation of Transportation and Sales of Natural Gas

 

The natural gas industry historically has been very heavily regulated. However, we do not believe that any action taken will affect us in a way that materially differs from the way it affects other natural gas producers.

 

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Historically, the transportation and sale for resale of natural gas in interstate commerce have been regulated by FERC under the Natural Gas Act of 1938, or NGA, the Natural Gas Policy Act of 1978, or NGPA, and regulations issued under those Acts. In the past, the federal government has regulated the prices at which natural gas could be sold. While sales by producers of natural gas can currently be made at unregulated market prices, it is conceivable that Congress could reenact price controls in the future. Deregulation of wellhead natural gas sales began with the enactment of the Natural Gas Policy Act and culminated in adoption of the Natural Gas Wellhead Decontrol Act which removed all price controls affecting wellhead sales of natural gas effective January 1, 1993.

 

FERC regulates interstate natural gas transportation rates and service conditions, which affects the marketing of natural gas that we produce as well as the revenues we receive for sales of our natural gas. Since 1985, FERC has endeavored to make natural gas transportation more accessible to natural gas buyers and sellers on an open access and non-discriminatory basis. FERC has stated that open access policies are necessary to improve the competitive structure of the interstate natural gas pipeline industry and to create a regulatory framework that will put natural gas sellers into more direct contractual relations with natural gas buyers by, among other things, unbundling the sale of natural gas from the sale of transportation and storage services.

 

Beginning in 1992, FERC issued a series of orders, beginning with Order No. 636, to implement its open access policies. As a result, the interstate pipelines’ historical role as wholesalers of natural gas was eliminated and replaced by a structure under which pipelines provide transportation and storage service on an open access basis to others who buy and sell natural gas. Although FERC does not directly regulate natural gas producers (except with respect to a producer’s role as a marketer of natural gas, where FERC does exercise certain limited jurisdiction as discussed below), the current FERC regulatory structure is intended to foster increased competition within all phases of the natural gas industry.

 

In 2000, FERC issued Order No. 637 and subsequent orders, which imposed a number of additional reforms designed to enhance competition in natural gas markets. Among other things, Order No. 637 revised FERC’s pricing policy by waiving price ceilings for short-term released capacity, and effected changes in FERC regulations relating to scheduling procedures, capacity segmentation, penalties, rights of first refusal and information reporting. FERC-regulated interstate pipelines’ tariffs now reflect the policies set forth in Order No. 637 and subsequent orders, and most major aspects of these policies that have been subject to court challenges have been upheld on judicial review. In 2008, FERC issued Order No. 712, which further modified applicable rules related to the release by shippers of interstate pipeline capacity, including through revisions intended to facilitate the use of interstate pipeline capacity by shippers. We cannot predict what action FERC will take on these matters in the future, or whether any such FERC’s actions will survive further judicial review. In recent years, FERC has made use of its anti-manipulation authority (discussed below) to extend its jurisdiction to entities such as producers whose role in the interstate natural gas market is typically limited to selling gas or transporting gas on interstate pipelines, including to develop and enforce its policies with respect to capacity release, open season bidding on new pipeline capacity, and related areas of FERC’s jurisdiction over interstate pipeline transportation. There are regulatory risks stemming from FERC’s aggressive enforcement of its regulations and policies related to pipeline capacity release, and the use of interstate pipeline capacity generally, by shippers like us.

 

The price at which we sell natural gas is not currently subject to federal rate regulation and, for the most part, is not subject to state regulation. However, with regard to our physical sales of these energy commodities, we are required to observe anti-market manipulation laws and related regulations enforced by FERC and/or the Commodity Futures Trading Commission, or the CFTC. See below the discussion of “Other federal laws and regulations affecting our industry—Energy Policy Act of 2005.” Should we violate the anti-market manipulation laws and regulations, we could also be subject to related third-party damage claims by, among others, sellers, royalty owners and taxing authorities. In addition, pursuant to FERC requirements regarding reporting by anyone who buys or sells more than a de minimis amount of natural gas in the interstate market introduced in Order No. 704, some of our operations may be required to annually report to FERC. Under these FERC reporting requirements, certain natural gas market participants must report information regarding their reporting of transactions to price index publishers and their blanket sales certificate status, as well as certain information

 

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regarding their wholesale, physical natural gas transactions for the previous calendar year depending on the volume of natural gas transacted. However, we do not report our gas sales transactions to price index publishers and therefore we do not have any regulatory requirements associated with reporting to price index publishers. If in the future we decided to report to price index publishers, there would be regulatory requirements to which we would be subject. See below the discussion of “Other federal laws and regulations affecting our industry—FERC Market Transparency Rules.”

 

Gathering services, which occur upstream of jurisdictional transmission services, are not regulated by FERC under the NGA and may be regulated by the states onshore and in state waters. FERC has reclassified certain jurisdictional transmission facilities as non-jurisdictional gathering facilities, which may increase our costs of getting gas to point of sale locations, since the rates charged for such gathering services are not subject to FERC regulation. State regulation of natural gas gathering facilities generally includes various safety, environmental and, in some circumstances, nondiscriminatory take requirements. Although such regulation has not generally been affirmatively applied by state agencies, natural gas gathering may receive greater regulatory scrutiny in the future.

 

Intrastate natural gas transportation and facilities are also subject to regulation by state regulatory agencies, and certain transportation services provided by intrastate pipelines are also regulated by FERC. The basis for intrastate regulation of natural gas transportation and the degree of regulatory oversight and scrutiny given to intrastate natural gas pipeline rates and services varies from state to state. Insofar as such regulation within a particular state will generally affect all intrastate natural gas shippers within the state on a comparable basis, we believe that the regulation of similarly situated intrastate natural gas transportation in any states in which we operate and ship natural gas on an intrastate basis will not affect our operations in any way that is of material difference from those of our competitors. Like the regulation of interstate transportation rates, the regulation of intrastate transportation rates affects the marketing of natural gas that we produce, as well as the revenues we receive for sales of our natural gas.

 

Regulation of Production

 

The production of oil and natural gas is subject to regulation under a wide range of local, state and federal statutes, rules, orders and regulations. Federal, state and local statutes and regulations require permits for drilling operations, drilling bonds and reports concerning operations. All of the states in which we own and operate properties have regulations governing conservation matters, including provisions for the unitization or pooling of oil and natural gas properties, the establishment of maximum allowable rates of production from oil and natural gas wells, the regulation of well spacing, and plugging and abandonment of wells. The effect of these regulations is to limit the amount of oil and natural gas that we can produce from our wells and to limit the number of wells or the locations at which we can drill, although we can apply for exceptions to such regulations or to have reductions in well spacing. Moreover, each state generally imposes a production or severance tax with respect to the production and sale of oil, natural gas and natural gas liquids within its jurisdiction.

 

The failure to comply with these rules and regulations could result in substantial penalties. Our competitors in the oil and natural gas industry are subject to the same regulatory requirements and restrictions that affect our operations.

 

Other Federal Laws and Regulations Affecting Our Industry

 

Energy Policy Act of 2005.    On August 8, 2005, President Bush signed into law the Domenici-Barton Energy Policy Act of 2005, or the EPAct 2005. EPAct 2005 is a comprehensive compilation of tax incentives, authorized appropriations for grants and guaranteed loans, and significant changes to the statutory policy that affects all segments of the energy industry. Among other matters, EPAct 2005 amends the NGA to add an anti- manipulation provision which makes it unlawful for any entity to engage in prohibited behavior to be prescribed by FERC, and furthermore provides FERC with additional civil penalty authority. EPAct 2005 provides FERC with the power to assess civil penalties of up to $1,000,000 per day for violations of the NGA and increases

 

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FERC’s civil penalty authority under the NGPA from $5,000 per violation per day to $1,000,000 per violation per day. The civil penalty provisions are applicable to entities that engage in the sale of natural gas for resale in interstate commerce. On January 19, 2006, FERC issued Order No. 670, a rule implementing the anti- manipulation provision of EPAct 2005, and subsequently denied rehearing. The rule makes it unlawful for any entity, directly or indirectly: (1) in connection with the purchase or sale of natural gas subject to the jurisdiction of FERC, or the purchase or sale of transportation services subject to the jurisdiction of FERC, to use or employ any device, scheme or artifice to defraud; (2) to make any untrue statement of material fact or omit to make any such statement necessary to make the statements made not misleading; or (3) to engage in any act or practice that operates as a fraud or deceit upon any person. The anti-manipulation rules do not apply to activities that relate only to intrastate or other non-jurisdictional sales or gathering, but do apply to activities of gas pipelines and storage companies that provide interstate services, such as Section 311 service, as well as otherwise non- jurisdictional entities to the extent the activities are conducted “in connection with” gas sales, purchases or transportation subject to FERC jurisdiction, which now includes the annual reporting requirements under Order 704. The anti-manipulation rules and enhanced civil penalty authority reflect an expansion of FERC’s NGA enforcement authority. Should we fail to comply with all applicable FERC administered statutes, rules, regulations, and orders, we could be subject to substantial penalties and fines.

 

FERC Market Transparency Rules.    On December 26, 2007, FERC issued a final rule on the annual natural gas transaction reporting requirements, as amended by subsequent orders on rehearing, or Order No. 704. Under Order No. 704, wholesale buyers and sellers of more than 2.2 million MMBtu of physical natural gas in the previous calendar year, including interstate and intrastate natural gas pipelines, natural gas gatherers, natural gas processors, natural gas marketers and natural gas producers, are required to report, on May 1 of each year, aggregate volumes of natural gas purchased or sold at wholesale in the prior calendar year to the extent such transactions utilize, contribute to or may contribute to the formation of price indices. It is the responsibility of the reporting entity to determine which individual transactions should be reported based on the guidance of Order No. 704. Order No. 704 also requires market participants to indicate whether they report prices to any index publishers and, if so, whether their reporting complies with FERC’s policy statement on price reporting. FERC has requested comments on whether it should require quarterly reporting of some natural gas transactions. In October 2011, the U.S. Court of Appeals for the 5th Circuit struck down other FERC regulations designed to promote market transparency that extended new reporting requirements to other entities (in this case certain non- interstate pipelines) historically outside of FERC’s jurisdiction. These rules, originally set forth in Order No. 720, were vacated by the court because they were found to exceed the scope of FERC’s authority under the NGA.

 

Additional proposals and proceedings that might affect the natural gas industry are pending before Congress, FERC and the courts. We cannot predict the ultimate impact of these or the above regulatory changes to our natural gas operations. We do not believe that we would be affected by any such action materially differently than similarly situated competitors.

 

Environmental, and Occupational Health and Safety Regulation

 

Our exploration, development and production operations are subject to various federal, state and local laws and regulations governing occupational health and safety, the discharge of materials into the environment or otherwise relating to environmental protection. These laws and regulations may, among other things, require the acquisition of permits to conduct exploration, drilling and production operations or other regulated activities; govern the amounts and types of substances that may be released into the environment in connection with oil and natural gas drilling and production; restrict the way we handle or dispose of our wastes; limit or prohibit construction or drilling activities in environmentally sensitive areas such as wetlands, wilderness areas or areas inhabited by endangered or threatened species; require investigatory and remedial actions to mitigate pollution conditions caused by our operations or attributable to former operations; impose specific health and safety criteria addressing worker protection; and impose obligations to reclaim and abandon well sites and pits. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations and the issuance of orders enjoining some or all of our operations in affected areas.

 

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These laws and regulations may also restrict the rate of oil and natural gas production below the rate that would otherwise be possible. The regulatory burden on the oil and natural gas industry increases the cost of doing business in the industry and consequently affects profitability. Additionally, Congress and federal and state agencies frequently revise environmental and worker health and safety laws and regulations, and any changes that result in more stringent and costly well drilling, construction, completion or water management activities, or waste handling, disposal, cleanup and remediation requirements for the oil and natural gas industry could have a significant impact on our operating costs and financial position. We may be unable to pass on such increased compliance costs to our customers. Moreover, accidental releases or spills may occur in the course of our operations, and we cannot assure you that we will not incur significant costs and liabilities as a result of such releases or spills, including any third-party claims for damage to property, natural resources or persons. While we believe that we are in material compliance with existing environmental laws and regulations and that such continued compliance with current requirements would not have a material adverse effect on our financial condition or results of operations, there is no assurance that this trend will continue in the future.

 

The following is a summary of the more significant existing environmental and occupational health and safety laws and regulations, as amended from time to time, to which our business operations are subject and for which compliance may have a material adverse impact on our capital expenditures, results of operations or financial position.

 

Hazardous Substances and Waste

 

The Comprehensive Environmental Response, Compensation, and Liability Act, or CERCLA, and comparable state laws impose liability without regard to fault or the legality of the original conduct on certain classes of persons who are considered to be responsible for the release of a “hazardous substance” into the environment. These persons include current and prior owners or operators of the site where the release occurred and entities that disposed or arranged for the disposal of the hazardous substances found at the site. Under CERCLA, these “responsible persons” may be subject to joint and several, strict liability for the costs of responding to the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. It is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances or other pollutants into the environment. We generate materials in the course of our operations that may be regulated as hazardous substances.

 

We also are subject to the requirements of the Resource Conservation and Recovery Act, or RCRA, and comparable state statutes, which impose strict requirements on the generation, storage, treatment, transportation and disposal of non-hazardous and hazardous wastes. Under the auspices of the EPA, most states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. Drilling fluids, produced waters and most of the other wastes associated with the exploration, development and production of oil or natural gas, if properly handled, are exempt from regulation as hazardous waste under Subtitle C of RCRA. These wastes, instead, are regulated under RCRA’s less stringent nonhazardous waste provisions, state laws or other federal laws. However, it is possible that certain oil and natural gas exploration, development and production wastes now classified as nonhazardous wastes could be classified as hazardous wastes in the future. A loss of the RCRA exclusion for drilling fluids, produced waters and related wastes could result in an increase in our costs to manage and dispose of generated wastes, which could have a material adverse effect on our results of operations and financial position. In the course of our operations we generate petroleum hydrocarbon wastes and ordinary industrial wastes that may be regulated as hazardous wastes.

 

We currently own or lease, and have in the past owned or leased, properties that have been used for numerous years to explore and produce oil and natural gas. Although we have utilized operating and disposal practices that were standard in the industry at the time, petroleum hydrocarbons and wastes may have been disposed of or released at or from the properties owned or leased by us or at or from the other locations where

 

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these petroleum hydrocarbons and wastes have been taken for treatment or disposal. In addition, certain of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons and wastes was not under our control. These properties and wastes disposed thereon may be subject to CERCLA, RCRA and analogous state laws. Under these laws, we could be required to remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to clean up contaminated property (including contaminated groundwater) and to perform remedial operations to prevent future contamination.

 

Air Emissions

 

On April 17, 2012, the EPA approved final rules that subject all oil and natural gas operations (production, processing, transmission, storage and distribution) to regulation under the NSPS and NESHAPS programs. These rules also include NSPS standards for completions of hydraulically fractured gas wells. These standards include the REC techniques developed in the EPA’s Natural Gas STAR program along with pit flaring of gas not sent to the gathering line. The standards are applicable to certain newly drilled and fractured wells as well as certain existing wells that are refractured. Further, the regulations under NESHAPS include MACT standards for those glycol dehydrators and storage vessels at major sources of hazardous air pollutants not currently subject to MACT standards. We currently do not believe that compliance with these NSPS and NESHAPS requirements will have a materially adverse effect on our results of operations or financial condition. Nonetheless while these rules have been finalized, many of the rules’ provisions will be phased-in over time, with the more stringent requirements like REC not becoming effective until January 1, 2015. On April 15, 2014, EPA released technical papers focused on potentially significant sources of air emissions from the oil and gas sector, EPA has indicated it will use this information and input from the public to assess how to pursue emission reductions from the oil and gas sector.

 

Climate Change

 

On December 15, 2009, the EPA published its findings that emissions of carbon dioxide, methane and other “greenhouse gases” present an endangerment to human health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth’s atmosphere and other climatic changes. These findings by the EPA have allowed the agency to proceed with the adoption and implementation of regulations restricting emissions of greenhouse gases under existing provisions of the federal Clean Air Act.

 

Among other things, EPA regulations now require specified large greenhouse gas emitters in the United States including companies in the energy industry to annually report those emissions. Additionally, starting in 2011, new sources or modifications of existing sources of significant quantities of greenhouse gas emissions that are already subject to regulation as major sources of conventional pollutants are required to obtain permits—and to use best available control technology to control those emissions—pursuant to the Clean Air Act as a prerequisite to the development of that greenhouse gas emissions source. While these regulations have not to date materially affected the company, such regulations may over time require us to incur costs to reduce emissions of greenhouse gases associated with our operations or could adversely affect demand for the oil and natural gas we produce.

 

Additionally, from time to time over the past several years, the U.S. Congress has considered legislation to restrict or regulate emissions of greenhouse gases. It presently appears unlikely that comprehensive climate legislation will be passed by either house of Congress in the near future, although energy legislation and other initiatives continue to be proposed that may be relevant to greenhouse gas emissions issues. In addition, a number of the states, either individually or through multi-state regional initiatives, address greenhouse gas emissions, primarily through the development of emission inventories or regional greenhouse gas cap and trade programs. Although most of the state-level initiatives have to date been focused on large sources of greenhouse gas emissions, such as electric power plants, it is possible that smaller sources could become subject to greenhouse gas-related regulation. Depending on the particular program, we could be required to control emissions or to purchase and surrender allowances for greenhouse gas emissions resulting from our operations.

 

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Any future federal laws or implementing regulations that may be adopted to address greenhouse gas emissions could require us to incur increased operating costs and could adversely affect demand for the oil and natural gas we produce.

 

Finally, it should be noted that some scientists have concluded that increasing concentrations of greenhouse gases in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, floods and other climatic events. If any such effects were to occur, they could have an adverse effect on our exploration and production operations. Significant physical effects of climate change could also have an indirect effect on our financing and operations by disrupting the transportation or process-related services provided by midstream companies, service companies or suppliers with whom we have a business relationship. We may not be able to recover through insurance some or any of the damages, losses, or costs that may result from potential physical effects of climate change.

 

Water Discharges and Subsurface Injections

 

The Federal Water Pollution Control Act, or the Clean Water Act, and analogous state laws impose restrictions and strict controls regarding the discharge of pollutants, including oil and hazardous substances, into navigable waters. Pursuant to the Clean Water Act and analogous state laws, permits must be obtained to discharge pollutants into state waters or waters of the United States, including wetlands. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by EPA or analogous state agency. The term “waters of the United States” has been broadly defined to include certain inland water bodies, including certain wetlands and intermittent streams. On April 21, 2014, the EPA proposed a new definition of “waters of the United States” that, if finalized, would tend to broaden rather than narrow the scope. Spill prevention, control and countermeasure requirements under the Clean Water Act require appropriate containment berms and similar structures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture or leak. In addition, the Clean Water Act and analogous state laws require individual permits or coverage under general permits for discharges of storm water runoff from certain types of facilities. The Clean Water Act also prohibits the discharge of dredge and fill material in regulated waters, including wetlands, unless authorized by permit. Moreover, the EPA is developing pretreatment standards and effluent limitations for the discharge of wastewater from hydraulic fracturing activities and plans to propose these standards for shale gas by 2014. Federal and state regulatory agencies can impose administrative, civil and criminal penalties, as well as require remedial or mitigation measures, for noncompliance with discharge permits or other requirements of the Clean Water Act and analogous state laws and regulations.

 

The Oil Pollution Act of 1990, or OPA, amends the Clean Water Act and establishes strict liability for owners and operators of facilities that are the site of a release of oil into waters of the United States. The OPA and its associated regulations impose a variety of requirements on responsible parties related to the prevention of oil spills and liability for cleanup costs and natural resource damages as well as a variety of public and private damages resulting from such spills. A “responsible party” under the OPA includes owners and operators of certain onshore facilities from which a release may affect waters of the United States.

 

Our oil and natural gas exploration and production operations generate produced water, drilling muds and other waste streams, some of which may be disposed by injection in underground wells situated in non-producing subsurface formations. The drilling and operation of these injection wells are regulated by the SDWA and analogous state and local laws. The Underground Injection Well Program under the SDWA requires that we obtain permits from the EPA or analogous state agencies for our disposal wells, establishes minimum standards for injection well operations, restricts the types and quantities of fluids that may be injected and prohibits the migration of fluid containing any contaminants into underground sources of drinking water. Any leakage from the subsurface portions of the injection wells may cause degradation of freshwater, potentially resulting in cancellation of operations of a well, imposition of fines and penalties from governmental agencies, incurrence of expenditures for remediation of affected resources, and imposition of liability by landowners or other parties claiming damages for alternative water supplies, property damages, and personal injuries. While we believe that we have obtained the necessary permits from the applicable regulatory agencies for our underground injection

 

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wells and that we are in substantial compliance with permit conditions and federal and state rules, any changes in the laws or regulations or the inability to obtain permits for new injection wells in the future may affect our ability to dispose of produced waters and would ultimately increase the cost of our operations, which costs could be significant. Furthermore, in response to recent seismic events near underground injection wells used for the disposal of oil and gas-related wastewaters, federal and some state agencies have begun investigating whether such wells have caused increased seismic activity, and some states have shut down or imposed moratoria on the use of such injection wells. If new regulatory initiatives are implemented that restrict or prohibit the use of underground injection wells in areas where we rely upon the use of such wells in our operations, our costs to operate may significantly increase and our ability to conduct continue production may be delayed or limited, which could have a material adverse effect on our results of operations and financial position.

 

Endangered Species Act, Migratory Birds, Natural Resources Damages

 

The ESA and analogous state laws provides broad protection for species of fish, wildlife and plants that are listed as threatened or endangered in the United States, and may adversely impact exploration, development and production activities by restricting activities that may affect such species or their habitats. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act. The ESA prohibits the harming of endangered or threatened species, provides for habitat protection, and imposes stringent penalties for noncompliance. While some of our facilities may be located in areas that are designated as habitat for endangered or threatened species, we believe that we are in substantial compliance with the ESA. Complying with these protections provided for endangered or threatened species could cause us to incur additional costs or become subject to operating restrictions or bans in the affected areas.

 

Moreover, as a result of a settlement reached in 2011, the FWS is required to make a determination on whether to list numerous species as endangered or threatened under the ESA over the next several years. For example, on March 27, 2014, the FWS announced the listing of the lesser prairie chicken, whose habitat is over a five-state region, including Texas where we operate, as a threatened species under the ESA. However, the FWS also announced a final rule that will limit regulatory impacts on landowners and businesses from the listing if those landowners and businesses have entered into certain range-wide conservation planning agreements, such as those developed by the WAFWA, pursuant to which such parties agreed to take steps to protect the lesser prairie chicken’s habitat and to pay a mitigation fee if its actions harm the lesser prairie chicken’s habitat. The final designation of previously unprotected species in areas where we operate as threatened or endangered could cause us to incur increased costs arising from species protection measures or could result in limitations, delays, or prohibitions on our exploration and production activities that could have an adverse impact on our ability to develop and produce our reserves.

 

Activities on Federal Lands

 

Oil and natural gas exploration, development and production activities on federal lands, including Indian lands and lands administered by the federal Bureau of Land Management (“BLM”), are subject to the National Environmental Policy Act, as amended (“NEPA”). NEPA requires federal agencies, including the BLM, to evaluate major agency actions having the potential to significantly impact the environment. In the course of such evaluations, an agency will prepare an Environmental Assessment that assesses the potential direct, indirect and cumulative impacts of a proposed project and, if necessary, will prepare a more detailed Environmental Impact Statement that may be made available for public review and comment. We have minimal exploration and production activities on federal lands. However, for those current activities as well as for future or proposed exploration and development plans on federal lands, governmental permits or authorizations that are subject to the requirements of NEPA are required. This process has the potential to delay or limit, or increase the cost of, the development of oil and natural gas projects. Authorizations to conduct activities on federal lands are also subject to protest, appeal or litigation, including also the sufficiency of the NEPA analysis, and such challenges may delay or halt projects. Additionally, the U.S. Department of the Interior, Bureau of Land Management has re-proposed rules in May 2013 that would impose new requirements on hydraulic fracturing operations

 

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conducted on federal lands. The rule would require companies to publicly disclose the chemicals used in hydraulic fracturing operations after fracturing operations have been completed and includes provisions addressing well-bore integrity and flowback water management plans.

 

Employee Health and Safety

 

We are subject to a number of federal and state laws and regulations, including the federal Occupational Safety and Health Act, or OSHA, and comparable state statutes, whose purpose is to protect the health and safety of workers. In addition, the OSHA hazard communication standard, the EPA community right-to-know regulations and comparable state statutes require that information be maintained concerning hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and citizens. We believe that we are in material compliance with all applicable laws and regulations relating to worker health and safety.

 

Legal Proceedings

 

Although we may, from time to time, be involved in litigation and claims arising out of our operations in the normal course of business, we are not currently a party to any material legal proceeding. In addition, we are not aware of any material legal or governmental proceedings contemplated to be brought against us.

 

Employees

 

As of August 31, 2014, we employed 69 people, including 9 employees in geology and geographic information systems, 17 employees in operations and engineering, 16 employees in accounting and finance, 17 employees in land/land administration and 10 employees in management, administration, legal and communications. Our future success will depend partially on our ability to attract, retain and motivate qualified personnel. We are not a party to any collective bargaining agreements and have not experienced any strikes or work stoppages. We consider our relations with our employees to be satisfactory. From time to time we utilize the services of independent contractors to perform various field and other services.

 

Offices

 

We currently lease approximately 23,557 square feet of office space in Fort Worth, Texas at Two City Place, Suite 1700, 100 Throckmorton, where our principal offices are located. The lease for our Fort Worth office expires in December 2015.

 

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MANAGEMENT

 

Directors and Executive Officers

 

The following table sets forth information regarding our directors and executive officers as of August 31, 2014. There are no family relationships among any of our directors or executive officers.

 

Name

   Age     

Position

B. Hunt Pettit

     44       President and Chief Executive Officer, Director

Brian C. Nelson

     44       Executive Vice President and Chief Financial Officer, Director

David L. Patty, Jr.

     44       Executive Vice President—Land and Business Development, Director

Lawrence B. Van Ingen

     61       Executive Vice President—Geology, Director

Tom D. McNutt

     45       Executive Vice President, General Counsel and Secretary, Director

John T. Richards

     60       Executive Vice President and Chief Operating Officer, Director

Jamie “Jim” M. Howe

     54       Executive Vice President and Chief Accounting Officer

Don Dimitrievich

     42       Director

 

Set forth below is the description of the backgrounds of our directors and executive officers.

 

B. Hunt Pettit, President and Chief Executive Officer, Director

 

Mr. Pettit has served as our President and Chief Executive Officer and Director since our formation in February 2006 and has over 19 years of experience in the oil and natural gas industry as an entrepreneur and landman. An early mover in the Eagle Ford shale, Mr. Pettit identified numerous opportunities across the play between 2008 and 2010. Under his leadership, we acquired and divested over 125,000 acres of leases in the Eagle Ford shale to numerous large independent oil and natural gas companies including Murphy E&P USA, Chesapeake Energy Corporation, Comstock Resources, Inc. and Hess Corporation. Prior to founding our company, Mr. Pettit served as Contract Land Manager for the Barnett shale project for David H. Arrington Oil & Gas, Inc. from May 2005 to February 2008. Mr. Pettit earned a Bachelor of General Studies in Biology, Chemistry and Philosophy from Texas Tech University.

 

Mr. Pettit has extensive knowledge of our operations and of the oil and natural gas industry. For these reasons, we believe Mr. Pettit is qualified to serve as a director of our company.

 

Brian C. Nelson, Executive Vice President and Chief Financial Officer, Director

 

Mr. Nelson has served as our Executive Vice President and Chief Financial Officer since September 2011 and became a Director of our company in April 2013. Mr. Nelson has 22 years of experience in the energy industry, including 13 years in oil and natural gas. Prior to joining us, he served as the Chief Financial Officer at ZaZa Energy, LLC from May 2011 to September 2011. From October 2010 to May 2011, Mr. Nelson served as Senior Vice President and Chief Financial Officer of Great Western Oil & Gas Company, LLC. From September 2002 to October 2010, Mr. Nelson served as Vice President of Finance of ATP Oil & Gas Corporation. From 2001 to 2002, he worked as an equity analyst with Frost Securities, Inc., covering exploration and production companies. Mr. Nelson earned a Master of Business Administration from Rice University and Bachelor of Arts in Economics from the University of Texas at Austin.

 

David L. Patty, Jr., Executive Vice President—Land and Business Development, Director

 

Mr. Patty has served as our Vice President—Land and Business Development since August 2010 and became a Director of our company in April 2013. Mr. Patty has over eight years of experience in the oil and natural gas industry with respect to acquisitions, divestitures, contract administration and operations. Mr. Patty worked under contract from July 2006 to April 2012 as a landman for David H. Arrington Oil and Gas, Inc.,

 

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Quicksilver Resources Inc. and DLP Resources LLC, serving in various positions while handling all aspects of the land and legal parameters of the exploration and development process from lease negotiations, title, due diligence, curative, urban well permitting, overseeing field brokers and acquisitions and divestitures. Mr. Patty earned a Juris Doctor from the University of Houston Law Center and a Bachelor of Arts in Government from the University of Texas at Austin.

 

Lawrence “Laurie” Van Ingen, Executive Vice President—Geology, Director

 

Mr. Van Ingen has served as our Executive Vice President—Geology since October 2010 and became a Director of our company in April 2013. Mr. Van Ingen has over 36 years of diversified domestic and international technical and management experience in the oil and natural gas industry in North America, Europe and Asia, including several countries in the Far East and South Pacific. Prior to joining us, Mr. Van Ingen was a co-owner of Alpine Ventures International, LLC, a company that has provided us with consulting services since November 2010. From March 2003 to November 2010, he was the President of Amana Partners, Inc., an oil and natural gas exploration and development company. Prior to that, he was employed from 1997 to 1999 by Pitts Energy Group. Mr. Van Ingen began his career at Mobil Corporation, where he lived and worked in a variety of domestic and international locations for 19 years and was promoted to positions of increasing responsibility. Mr. Van Ingen earned a Master of Science in Geology from the University of Wyoming and a Bachelor of Arts in Geology from Alfred University.

 

Tom D. McNutt, Executive Vice President, General Counsel and Secretary, Director

 

Mr. McNutt has served as our Executive Vice President, General Counsel and Secretary since March 2012 and became a Director of our company in April 2013. Mr. McNutt has over 13 years of legal experience. From January 2009 to March 2012, Mr. McNutt was of counsel, and from June 2001 to January 2009, he was an associate, in the tax group of Bracewell & Giuliani, LLP. While at Bracewell & Giuliani, LLP Mr. McNutt advised numerous oil and natural gas clients on a variety of issues including international, federal and state tax issues and also designed and implemented tax efficient structures with respect to asset acquisitions and dispositions. Mr. McNutt earned a Master of Laws (LLM) in taxation from the New York University School of Law and a Juris Doctor from South Texas College of Law where he graduated cum laude. He also earned a Bachelor of Arts in Economics from the University of Texas at Austin.

 

John Richards, Executive Vice President and Chief Operating Officer, Director

 

Mr. Richards has served as our Executive Vice President and Chief Operating Officer since May 2013 and became a Director of our Company in August 2013. Mr. Richards has 36 years of technical, operations and management experience in the energy industry. Prior to joining us, Mr. Richards served as Partner at Valens Energy, LP, a consulting services firm he founded which focuses on well design and construction for drilling, completion and production operations. Prior to that, he served as Executive Vice President of Operations at ZaZa Energy from July 2010 to January 2013, where he established the operating group for the startup company. Prior to joining ZaZa Energy, Mr. Richards served as Engineering Advisor and Drilling Group Lead for EnCana Oil & Gas (USA), Inc. from April 2007 to June 2010. From 1981 to 2007, Mr. Richards served in multiple operational and managerial capacities with increasing responsibility, both domestically and internationally, with Anadarko Petroleum Corporation (UPRC/Champlin Petroleum). Mr. Richards received a B. S. in Mechanical Engineering from Louisiana Tech University.

 

Jamie “Jim” M. Howe, Executive Vice President and Chief Accounting Officer

 

Mr. Howe has served as our Executive Vice President and Chief Accounting Officer since September 2013. He has over 20 years of experience in several segments of the energy industry including exploration and production, midstream and oil field services. Prior to joining us, he served as Vice President of Copano Energy, and the Texas segment Controller, from November 2011 to June 2013. He worked for Crosstex Energy Services

 

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from 2004 until November 2011, initially as Director of Internal Audit and, beginning in 2006, as Vice President, Gas and Liquids Accounting. From 1998 to 2002, Mr. Howe was a manager in the energy industry consulting practice of Arthur Andersen LLP. Prior to joining Arthur Andersen, he worked at Baker Hughes and Pioneer Natural Resources in a variety of finance and accounting roles. Mr. Howe holds a Bachelor of Arts degree in English and Journalism from the University of Arkansas and is a Certified Public Accountant.

 

Don Dimitrievich, Director

 

Mr. Dimitrievich became a Director of our company in April 2013. Mr. Dimitrievich is a Managing Director at Highbridge Principal Strategies, an alternative investment management organization that together with its affiliates manages over $30 billion in capital for institutional investors, pension funds, endowments and foundations. At Highbridge, Mr. Dimitrievich oversees Highbridge Principal Strategies’ direct credit investment strategy for the energy and power sectors. Prior to joining Highbridge in 2012, Mr. Dimitrievich was a Managing Director of Citi Credit Opportunities, a credit focused principal investment group. At Citi Credit Opportunities, Mr. Dimitrievich oversaw the energy and power portfolio and invested over $800 million in mezzanine, special situation and equity co-investments, and secondary market opportunities. Mr. Dimitrievich began his career as a corporate attorney in the New York office of Skadden, Arps, Slate, Meagher & Flom LLP from 1998 to 2004 focusing on energy mergers and acquisitions and capital markets transactions. Mr. Dimitrievich has a Law degree with Great Distinction from McGill University in Montreal, Canada and earned a Chemical Engineering degree with Great Distinction from Queen’s University in Kingston, Canada.

 

Board of Directors

 

Our board of directors currently consists of seven members. Effective upon completion of this offering, we expect certain of our existing directors will resign and we will appoint additional independent directors such that a majority of the members of our board of directors will be independent in accordance with NYSE listing standards.

 

In evaluating director candidates, we have assessed whether a candidate possesses the integrity, judgment, knowledge, experience, skills and expertise that are likely to enhance the board’s ability to manage and direct our affairs and business, including, when applicable, to enhance the ability of committees of the board to fulfill their duties.

 

Following the completion of this offering, our directors will be divided into three classes serving staggered three-year terms. Class I, Class II and Class III directors will serve until our annual meetings of stockholders in 2015, 2016 and 2017, respectively. At each annual meeting of stockholders held after the initial classification, directors will be elected to succeed the class of directors whose terms have expired. This classification of our board of directors could have the effect of increasing the length of time necessary to change the composition of a majority of the board of directors. In general, at least two annual meetings of stockholders will be necessary for stockholders to effect a change in a majority of the members of the board of directors.

 

Pursuant to a stockholders agreement among us and the holders of our outstanding capital stock and warrants, Mr. Pettit and Highbridge have certain rights, but no obligations, to nominate directors following completion of this offering. So long as Mr. Pettit and his affiliates hold in the aggregate 10% or more of the outstanding shares of our common stock, Mr. Pettit has the right to nominate (i) three directors if he owns 20% or more, (ii) two directors if he owns 15% or more, and (iii) one director if he owns 10% or more. So long as Highbridge and its affiliates hold in the aggregate 10% or more of the outstanding shares of our common stock, Highbridge has the right to nominate one director. The stockholders agreement also provides that, following consummation of this offering, our board of directors will consist of the number of directors that Mr. Pettit and Highbridge are entitled to nominate pursuant to the agreement, plus such number of additional directors that are independent as required under NYSE rules. We may not decrease or increase the number of directors to a number less than or greater than the number of directors required to comply with the agreement without the consent of

 

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Highbridge (so long as Highbridge and its affiliates hold in the aggregate 10% or more of the outstanding shares of our common stock and Mr. Pettit (so long as Pettit and his affiliates and members of his immediate family hold in the aggregate 10% or more of the outstanding shares of our common stock). Upon completion of this offering Highbridge and its affiliates and Mr. Pettit and his affiliates will own     % and     % of our common stock, respectively.

 

Pursuant to the stockholders agreement, we must cause the individuals designated by Mr. Pettit and Highbridge to be nominated for election to the board of directors, solicit proxies in favor thereof, and at each meeting of the stockholders of the company at which directors are to be elected recommend that the stockholders elect to the board each such individual nominated for election at such meeting. Mr. Pettit and Highbridge and each of their affiliates have agreed to vote all of their shares entitled to vote in the election of directors and to take such other necessary actions to elect such desginees.

 

Committees of the Board of Directors

 

Upon the conclusion of this offering, we intend to have an audit committee, a compensation committee, a nominating and governance committee and a reserve committee of our board of directors, and we may have such other committees as the board of directors determines from time to time. We anticipate that each of the standing committees of the board of directors will have the composition and responsibilities described below.

 

Audit Committee

 

We will establish an audit committee in connection with the completion of this offering. We anticipate that our audit committee will initially consist of three independent directors who are financially literate, one of whom will be an “audit committee financial expert” as described in Item 407(d)(5) of Regulation S-K. Our audit committee will oversee, review, act on and report to our board of directors on various auditing and accounting matters, including: the selection of our independent accountants, the scope of our annual audits, fees to be paid to our independent accountants, the performance of our independent accountants and our accounting practices. In addition, the audit committee will oversee our compliance programs related to legal and regulatory requirements. Upon formation of the audit committee, we expect to adopt an audit committee charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NYSE standards.

 

Compensation Committee

 

We will establish a compensation committee in connection with the completion of this offering. We anticipate that our compensation committee will initially consist of three independent directors. Our compensation committee will establish salaries, incentives and other forms of compensation for officers and other employees. Our compensation committee will also administer our incentive compensation and benefit plans. Upon formation of the compensation committee, we expect to adopt a compensation committee charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NYSE standards.

 

Nominating and Governance Committee

 

We will establish a nominating and governance committee in connection with the completion of this offering. We anticipate that our nominating and corporate governance committee will initially consist of three independent directors. Our nominating and corporate governance committee will identify, evaluate and recommend qualified nominees to serve on our board of directors, develop and oversee our internal corporate governance processes and maintain a management succession plan. Upon formation of the nominating and governance committee, we expect to adopt a nominating and governance committee charter defining the committee’s primary duties in a manner consistent with the rules of the SEC and NYSE standards.

 

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Reserve Committee

 

We will establish a reserve committee in connection with the completion of this offering. We anticipate that our reserve committee will initially consist of three independent directors. Our reserve committee will oversee the preparation by independent petroleum engineers of annual and any special reserve reports and/or audits of the estimated amounts of our hydrocarbon reserves and related information. Upon formation of the reserve committee, we expect to adopt a reserve committee charter defining the committee’s primary duties.

 

Compensation Committee Interlocks and Insider Participation

 

The directors serving on the compensation committee are not and will not at any time be one of our employees. None of our executive officers serve on the board of directors or compensation committee of a company that has an executive officer that serves on our board. No member of our board is an executive officer of a company in which one of our executive officers serves as a member of the board of directors or compensation committee of that company.

 

Code of Business Conduct and Ethics

 

Our board of directors will adopt a code of business conduct and ethics applicable to our employees, directors and officers, in accordance with applicable U.S. federal securities laws and the corporate governance rules of the NYSE. Any waiver of this code may be made only by our board of directors and will be promptly disclosed as required by applicable U.S. federal securities laws and the corporate governance rules of the NYSE. Our code of business conduct and ethics will be available on our corporate website at www.enxp.com on or prior to the completion of this offering.

 

Corporate Governance Guidelines

 

Our board of directors will adopt corporate governance guidelines in accordance with the corporate governance rules of the NYSE. Our code of corporate governance guidelines will be available on our corporate website at www.enxp.com on or prior to the completion of this offering.

 

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EXECUTIVE COMPENSATION

 

Summary Compensation Table

 

As an emerging growth company, we have opted to comply with the executive compensation disclosure rules applicable to “smaller reporting companies” as such term is defined in the rules promulgated under the Securities Act, which require compensation disclosure for our principal executive officer and the two most highly compensated executive officers other than our principal executive officer during the 2013 fiscal year. Throughout this prospectus, these three officers are referred to as our named executive officers.

 

The following table shows information concerning the annual compensation for services provided to us by our named executive officers during the fiscal years ended December 31, 2013 and 2012.

 

Name and Principal Position

   Year      Salary      Bonus      Stock
Awards(1)
     All Other
Compensation(2)
     Total  

B. Hunt Pettit

     2013       $ 265,856       $ —         $ —         $ —         $ 265,856   

President and Chief Executive Officer

     2012       $ 247,815       $ 100,000       $ —         $ —         $ 347,815   
                 

Brian C. Nelson

     2013       $ 251,892       $ —         $ —         $ —         $ 251,892   

Executive Vice President and Chief Financial Officer

     2012       $ 147,660       $ 100,000       $ 6,350,000       $ 84,375       $ 6,682,035   
                 

Tom D. McNutt

     2013       $ 237,500       $ —         $ —         $ —         $ 237,500   

Executive Vice President, General Counsel and Secretary

     2012       $ 150,000       $ 72,500       $ 1,270,000       $ 20,000       $ 1,512,500   
                 

 

(1)   Reflects the grant date fair value of restricted shares of our common stock granted during 2012. In accordance with FASB ASC Topic 718, we recognized a grant date fair value of $127 per share with respect to these awards based on a third party valuation. The agreements governing the restricted stock awards were amended on November 16, 2012, December 1, 2013 and, for Mr. Nelson, on March 31, 2014 to modify the vesting dates and percentage of shares vesting at each vesting date as described under “—Grants of Plan-Based Awards” below. The modifications subsequent to the grant date had no impact on the fair value of the restricted shares.
(2)   Overriding royalty interests payments of $3,098, $570 and $570 were made to Messrs. Pettit, Nelson and McNutt, respectively, during 2013. See “—Overriding Royalty Interests.” No payments related to the overriding royalty interests were made during 2012. Compensation for consulting services of $84,375 and $20,000 prior to employment were made to Messrs. Nelson and McNutt during 2012, respectively.

 

Employment Agreements

 

We will enter into employment agreements contemporaneously with the consummation of this offering with each of our named executive officers, the material terms of which are described below. Except as described below, each employment agreement will be executed with substantially similar terms and conditions.

 

Each employment agreement for our executives will have an initial             -year term and will automatically renew and extend for additional one-year terms unless written notice of non-renewal is delivered by either party to the other not less than 30 days prior to the expiration of the then-existing term. Each named executive officer will be entitled to, among other things, paid vacation, customary employee benefits as offered by us and reimbursement of business expenses. Each executive will be eligible to participate in the 2012 Stock Incentive Plan. Each executive will agree to maintain and protect the confidentiality of our information during and after his employment with us and will agree not to compete with us during his employment, or to solicit away any of our employees during his employment and for six months after termination of his employment.

 

The employment agreements with Messrs. Pettit, Nelson and McNutt will provide for annual base salaries of $         , $         and $         , respectively, subject to increase at our discretion, and an annual cash bonus, the

 

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amount of which shall be in the sole and absolute discretion of the compensation committee. Additionally, we will agree to nominate Mr. Pettit to serve on our board of directors and use our best efforts to cause him to be elected, appointed, or re-elected or re-appointed, as a director.

 

If the executive’s employment is terminated by us for cause (as defined in the employment agreement) or by the executive’s death or disability, or the executive voluntarily terminates his employment without good reason (as defined in the employment agreement), including a non-renewal by the executive, the executive will receive an amount consisting of the executive’s accrued and unpaid base salary and benefits payable under our benefit plan terms including equity plans (which we refer to collectively as accrued amounts) and, in the case of a termination due to the executive’s death or disability, an optional bonus at the discretion of the compensation committee. The executive will also be entitled to receive the following severance payments upon termination under the circumstances described below.

 

Termination by us without cause (excluding death or disability), including our failure to renew the employment agreement, or by the executive for good reason and no change in control (as defined in the employment agreement) occurred within the 24 month period immediately prior to the termination:

 

   

all accrued amounts;

 

   

the greater of (i) a pro rata amount of the executive’s target bonus for the year in which the termination occurs or (ii) a bonus for the year in which the termination occurs as determined by the compensation committee; and

 

   

provided the executive complies with the confidentiality, non-compete and non-solicitation provisions contained in the employment agreement and executes a release, a lump sum severance payment equal to the sum of:

 

   

the executive’s base salary for the year in which the termination occurs (or, if greater, the executive’s base salary for the year immediately preceding the year in which the termination occurs); plus

 

   

an amount equal to the greater of (i) the bonus payable to the executive for the year in which termination occurs (provided that if a bonus for such year has not been determined as of the date of termination, then the amount of the bonus will be 100% of the executive’s target bonus for such year, to the extent a target bonus exists) or (ii) the bonus paid to the executive for the year immediately preceding the year in which the termination occurs.

 

Termination by us without cause (excluding death or disability), including our failure to renew the employment agreement, or by the executive for good reason, within the 24-month period following a change in control:

 

   

all accrued amounts;

 

   

an optional bonus, at the discretion of the compensation committee;

 

   

an amount equal to the greater of:

 

   

a pro rata amount of the executive’s target bonus for the year in which the termination occurs; or

 

   

a bonus for such year as may be determined by the compensation committee in its sole discretion; and

 

   

provided the executive complies with the confidentiality, non-compete and non-solicitation provisions contained in the employment agreement and executes a release, a lump sum severance payment equal to the sum of:

 

   

            times the greater of (i) the executive’s base salary in effect as of the date of termination (or, if greater, before any reduction during the change of control period) or (ii) the executive’s base salary in effect immediately before the change of control occurs; plus

 

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            times the greater of (i) the bonus payable for the year in which the termination occurs (provided that if a bonus for such year has not been determined as of the date of termination, then the bonus amount will be 100% of the executive’s target bonus for such year, to the extent a target bonus exists), (ii) the bonus paid to the executive for the year immediately preceding the year in which the termination occurs; or (iii) the bonus paid to the executive for the year immediately preceding the year in which the change of control occurs.

 

The employment agreements generally define a change in control to mean any of the following events:

 

   

any person or group becomes the “beneficial owner” (as defined in Rule 13d-3 under the Exchange Act), directly or indirectly, of more than 35% of the total voting power of our outstanding voting stock;

 

   

our merger with or consolidation into another entity and, immediately after giving effect to the merger or consolidation, one or both of the following occurs: (a) less than 50% of the total voting power of the outstanding voting stock of the surviving or resulting entity is then “beneficially owned” in the aggregate by our stockholders immediately prior to such merger or consolidation, or (b) the individuals who were members of our board of directors immediately prior to the execution of the agreement providing for the merger or consolidation do not constitute at least a majority of the members of the board of directors of the surviving or resulting entity;

 

   

we sell, assign, convey, transfer, lease or otherwise dispose of all or substantially all of our assets to a third party in one transaction or a series of related transactions;

 

   

individuals who constitute our board of directors cease for any reason to constitute at least a majority of our board of directors unless such persons were elected, appointed or nominated by a vote of at least a majority of our incumbent directors; or

 

   

the complete liquidation or dissolution of us.

 

Grants of Plan-Based Awards

 

Share information in this section does not give effect to the     -for-1 stock split that we will effect immediately prior to the completion of this offering.

 

On August 22, 2012, Brian C. Nelson was awarded 50,000 restricted shares of our common stock. Pursuant to the original award agreement, 50% of such restricted shares vested on the earlier of January 1, 2013 or the completion of our initial public offering, and the remaining 50% vested on January 1, 2013. On November 16, 2012, the award agreement was amended to provide for 100% vesting on the earlier of January 1, 2014 or the completion of our initial public offering. On December 1, 2013, the award agreement was amended to provide for 100% vesting on March 31, 2014 and was subsequently amended on March 31, 2014 to provide for 100% vesting on August 15, 2014.

 

On August 22, 2012, Tom D. McNutt was awarded 10,000 restricted shares of our common stock. Pursuant to the original award agreements, the restricted shares vested ratably in three equal installments: the first vesting date was the earlier of January 1, 2013 or the completion of our initial public offering, and the second and third vesting dates were the first and second anniversaries of the first vesting date. On November 16, 2012, the award agreements were amended to provide that the first vesting date would be the earlier of January 1, 2014 or the completion of our initial public offering with the second and third vesting dates depending on the timing of the first vesting date. On December 1, 2013, the award agreements were amended to provide for 100% vesting upon the completion of our initial public offering. The restricted shares also vest upon a change in control or death or disability. If Mr. McNutt’s employment terminates during the restricted period for any reason other than death or disability, his unvested shares are automatically forfeited.

 

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Outstanding Equity Awards at Fiscal Year-End

 

Share information in this section does not give effect to the     -for-1 stock split that we will effect immediately prior to the completion of this offering.

 

The following table provides information concerning unvested restricted shares of our common stock held by our named executive officers as of December 31, 2013.

 

     Number of Restricted
Shares That Have
Not Vested(1)
     Market Value of
Restricted Shares That
Have Not Vested(2)
 

B. Hunt Pettit

     —         $ —     

Brian C. Nelson

     50,000       $ 6,350,000   

Tom D. McNutt

     10,000       $ 1,270,000   

 

(1)   Mr. Nelson’s restricted shares vested on August 15, 2014 and Mr. McNutt’s restricted shares will vest upon completion of this offering.
(2)   Reflects the grant date fair value of restricted shares of our common stock granted during 2012. In accordance with FASB ASC Topic 718, we recognized a grant date fair value of $127 per share with respect to these awards based on a third party valuation. The agreements governing the restricted stock awards were amended on November 16, 2012, December 1, 2013 and, for Mr. Nelson, on March 31, 2014 to modify the vesting dates and percentage of shares vesting at each vesting date as described under “—Grants of Plan-Based Awards” above. The modifications subsequent to the grant date had no impact on the fair value of the restricted shares.

 

Overriding Royalty Interests

 

In August 2012, we completed the granting of overriding royalty interests in our acreage to our executive officers, including the named executive officers and certain other members of management. These overriding royalty interests entitle the holders to receive percentages of the net revenue associated with sales of oil and natural gas produced from our acreage, with no corresponding responsibility for payment of any expenses. These percentages range from 0% to 2.0% in the East Texas stacked play, 0% to 2.2% in the Permian Basin and 0% to 4.2% in the DJ Basin. With respect to our named executive officers, B. Hunt Pettit, Brian C. Nelson and Tom D. McNutt received overriding royalty interests ranging from 0% to 4.2%, 0% to 0.25% and 0% to 0.25% respectively. In 2013, royalty payments to Messrs. Pettit, Nelson and McNutt were minimal, not exceeding approximately $3,000 each. As described under “Certain Relationships and Related Party Transactions—Corporate Reorganization,” certain other persons received overriding royalty interests in connection with our corporate reorganization. Since October 2012, we have not granted, and we do not intend to grant, additional overriding royalty interests with respect to our properties to our executive officers or other employees.

 

2012 Stock Incentive Plan

 

In connection with our corporate reorganization, we adopted our 2012 Stock Incentive Plan. We intend to amend and restate our 2012 Stock Incentive Plan in connection with the completion of this offering. The following is a summary of the amended and restated plan, which is filed as an exhibit to the registration statement of which this prospectus forms a part. The purpose of the plan is to enable us to attract and retain the types of employees, consultants and directors who will contribute to our long range success, provide incentives that align the interests of employees, consultants and directors with those of our stockholders and promote the success of our business.

 

Eligibility.    Employees, consultants and directors of us and our affiliates are eligible to participate in the plan.

 

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Administration.    Upon completion of this offering, our compensation committee will administer the plan and will generally be responsible for selecting participants from among eligible persons. Unless otherwise limited, the compensation committee will have broad discretion to administer the plan, including the power to determine to whom and when awards will be granted, to determine the amount of such awards (measured in cash, shares of common stock or otherwise), to prescribe the terms and conditions of each award, to accelerate the exercise terms of any award, to delegate duties under the plan and to execute all other responsibilities permitted or required under the plan.

 

Shares Available.    The maximum aggregate number of shares of our common stock that may be reserved and available for delivery in connection with awards under the plan is             , subject to adjustment in accordance with the terms of the plan,             of which have been issued. Shares covered by awards that terminate by expiration, forfeiture, cancellation, or otherwise without the issuance of shares or are settled in cash will not count against this limit and can be regranted under the plan. Shares surrendered or withheld in payment of the exercise price of an option and shares withheld by us to satisfy any tax withholding obligation will count against the limit. Subject to adjustment in accordance with the terms of the plan, no more than             shares may be subject to options or stock appreciation rights granted under the plan to any one participant during any one year period, and no more than             shares may be subject to any other awards granted under the plan to any one participant during any one year period.

 

Terms of Options.    The compensation committee may grant (a) incentive stock options that comply with Section 422 of the Code to our employees and (b) nonqualified options to any eligible person under the Plan. Except as described below, the exercise price for an option must not be less than the fair market value per share of common stock as of the date of grant and may be exercised on such terms as the compensation committee determines, but not later than ten years from the date of grant. For participants who own 10% or more of the voting power of our outstanding stock, the exercise price for an option must not be less than 110% of the fair market value per share of common stock as of the date of grant and is not exercisable after the expiration of five years from the date of grant.

 

Terms of Stock Appreciation Rights.    SARs may be awarded in connection with or separate from an option. A SAR is the right to receive an amount equal to the excess of the fair market value of one share of our common stock on the date of exercise over the grant price of the SAR. SARs will be exercisable on such terms as the compensation committee determines. The term of an SAR will be for a period determined by the compensation committee but will not exceed ten years. SARs may be paid in cash, common stock or a combination of cash and common stock, as determined by the compensation committee in the award agreement.

 

Restricted Stock Awards.    A restricted stock award is a grant of shares of common stock subject to a risk of forfeiture, restrictions on transferability and any other restrictions determined by the compensation committee. Except as otherwise provided under the terms of the plan or an award agreement, the holder of a restricted stock award may have rights as a stockholder, including the right to vote or to receive dividends (subject to any mandatory reinvestment or other requirements determined by the compensation committee). Unless otherwise determined by the compensation committee, a restricted stock award will be forfeited and reacquired by us upon termination of employment other than death or disability. Common stock distributed in connection with a stock split or stock dividend, and other property distributed as a dividend, may be subject to the same restrictions and risk of forfeiture as the restricted stock with respect to which the distribution was made.

 

Restricted Stock Units.    Restricted stock units are rights to receive cash, common stock or a combination of cash and common stock at the end of a specified period. Restricted stock units may be subject to restrictions, including a risk of forfeiture, as determined by the compensation committee. Restricted stock units may be satisfied by cash, common stock or any combination of cash and common stock, as determined by the compensation committee. Unless otherwise determined by the compensation committee, restricted stock units will be forfeited upon termination of a participant’s employment other than death or disability. The compensation committee may, in its sole discretion, grant dividend equivalents with respect to restricted stock units.

 

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Performance Awards.     The plan will provide for the grant of performance awards that may be granted in the form of cash, common stock or a combination of cash and common stock. Each performance award will set forth (a) the amount, including a target and maximum amount if applicable, the recipient may earn in the form of cash or shares of common stock or a formula for determining that amount, (b) the performance criteria and level of achievement versus the criteria that will determine the amount of cash payable or number of shares of our common stock to be granted, issued, retained and/or vested, (c) the performance period over which performance is to be measured, (d) the timing of any payments to be made, (e) restrictions on the transferability of the award and (f) such other terms and conditions as our compensation committee may determine. The maximum performance award payable to any one participant under the plan is                  shares of common stock, or cash equivalent thereof as determined by the compensation committee, and the maximum cash bonus that may be paid to any participant in any calendar year is $             million.

 

Director Compensation

 

We did not award any compensation to any non-employee director during 2012 or 2013. However, our board of directors believes that attracting and retaining qualified non-employee directors will be critical to the future value growth and governance. Our board of directors also believes that the compensation package for our non-employee directors should require a significant portion of the total compensation package to be equity-based to align the interests of these directors with our stockholders.

 

The following sets forth the compensation policy for our non-employee directors to be effective upon completion of this offering. Our non-employee director compensation policy is subject to annual review by our compensation committee.

 

Our board of directors has implemented a compensation policy applicable to all of our non-employee directors, which provides all non-employee directors the following compensation for board and committee services on an annual basis:

 

   

Each non-employee director shall receive $         in cash, shares of our restricted common stock valued at $         that vest annually, $         in cash per meeting attended in person (capped at $         per year) and $         in cash per meeting held by telephone;

 

   

The chairman of each of the audit committee, the reserve committee and the compensation committee shall receive $         in cash and shares of our restricted common stock valued at $         that vest annually;

 

   

The chairman of the nominating and corporate governance committee shall receive $         in cash and shares of our restricted common stock valued at $         that vest annually;

 

   

Each member of the audit committee, the reserve committee and the compensation committee (other than the chairman) shall receive $         in cash, $         per meeting attended in person and $         in cash per meeting held by telephone; and

 

   

Each member of the nominating and corporate governance committee (other than the chairman) shall receive $         in cash, $         per meeting attended in person and $         in cash per meeting held by telephone

 

Directors who are also our employees will not receive any additional compensation for their service on the board of directors.

 

We expect that each director will be reimbursed for (1) travel and miscellaneous expenses to attend meetings and activities of our board of directors or its committees; (2) travel and miscellaneous expenses related to such director’s participation in our general education and orientation program for directors; and (3) travel and miscellaneous expenses for each director’s spouse who accompanies a director to attend meetings and activities of our board of directors or any of our committees.

 

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CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS

 

Corporate Reorganization

 

We were incorporated on July 31, 2012 pursuant to the laws of the State of Delaware as Energy & Exploration Partners, Inc. to become a holding company for our business. In August 2012, we completed a series of reorganization transactions described below, which we refer to collectively as our corporate reorganization.

 

Prior to the completion of our corporate reorganization, our business was conducted through two entities directly or indirectly owned and controlled by Hunt Pettit, our founder, President and Chief Executive Officer: Energy & Exploration Partners, LLC, or ENXP LLC, which owns our existing acreage, and Energy & Exploration Partners Operating, LP, which was formed to conduct our drilling operations.

 

In 2011, Mr. Pettit and certain investors formed North American Shale Investment Fund, LP, or NASIF, to acquire net profits interests and overriding royalty interests in certain of our acreage. Mr. Pettit owned all of the equity interests in the general partner of NASIF, and the other investors owned all of the limited partner interests in NASIF. Mr. Pettit also owned all of the outstanding equity interests in North American Shale Investment Advisors, LLC, or NASIF Advisors, which was a party to an investment management agreement with NASIF. In addition to the net profits interests in our acreage owned by NASIF, certain investors, which we refer to as the DJ Basin investors, owned additional net profits interests in our DJ Basin acreage.

 

The purpose of the corporate reorganization was twofold: (1) as it related to the entities owned by Mr. Pettit through which our business was previously conducted, to reorganize those entities as a corporation for the purpose of effecting an initial public offering, and (2) to acquire the net profits interests in our acreage held by NASIF and the DJ Basin investors.

 

Our corporate reorganization consisted of the following transactions (share information in the following description does not give effect to the -for-1 stock split that we will effect immediately prior to the completion of this offering):

 

Contributions to Energy & Exploration Partners, Inc.    Pursuant to a contribution agreement, on August 22, 2012, the following contributions were made to us:

 

   

Mr. Pettit, our founder, President and Chief Executive Officer, and an affiliated entity contributed the following interests to us in exchange for 288,031 shares of our common stock:

 

   

all of the outstanding equity interests in ENXP, LLC;

 

   

all of the outstanding equity interests in Energy & Exploration Partners Operating, LP and in its general partner; and

 

   

all of the outstanding equity interests in the general partner of NASIF and in NASIF Advisors;

 

   

the limited partners of NASIF contributed all of the outstanding limited partner interests in NASIF to us in exchange for 99,999 shares of our common stock; and

 

   

certain of the DJ Basin investors contributed their net profits interests in our DJ Basin acreage to us in exchange for 8,470 shares of our common stock.

 

The consideration for the contributions described above was determined through negotiations among us and the other parties to the contribution agreement. These negotiations were conducted primarily between our management, including our Chief Financial Officer and our General Counsel in consultation with Mr. Pettit, on one hand, and representatives of the largest limited partner of NASIF, on the other hand. These parties used common industry valuation methodologies, including analysis of available information regarding other transactions in our core areas, to assess the relative value of the net profits interests in our acreage held by NASIF compared to the value of our business as a whole. On the basis of these assessments, our management

 

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and the NASIF limited partners negotiated the percentage of our company’s equity to be received by the NASIF limited partners in exchange for their interests in NASIF. We then used the same principles to determine the amount of equity in our company to be offered to the DJ Basin investors in exchange for their net profits interests in our acreage. Mr. Pettit, as the sole direct or indirect equity owner of the companies that comprised our business prior to the reorganization, received the remainder of the equity in our company, other than the restricted stock awarded to our management as described below.

 

No value was attributed to Mr. Pettit’s interests in the general partner of NASIF and NASIF Advisors in the negotiation of the terms of the contribution agreement. Mr. Pettit acquired his interests in each of these entities upon their formation for de minimis capital contributions to the entities.

 

Immediately prior to the contributions described above, the limited partners of NASIF and the DJ Basin investors received overriding royalty interests in our acreage. For additional information regarding these overriding royalty interests and overriding royalty interests held by our executive officers, certain other members of our management and an entity affiliated with one of our non-employee directors, see “—Overriding Royalty Interests” and “Executive Compensation—Overriding Royalty Interests.” Additionally, we repurchased the net profits interests held by the DJ Basin investors that were not parties to the contribution agreement for total cash payments of $1.7 million.

 

Following the contributions described above, we assigned our interests in Energy & Exploration Partners Operating, LP and in its general partner to ENXP, LLC. Additionally, NASIF, its general partner and NASIF Advisors were merged into ENXP, LLC, the investment management agreement between NASIF and NASIF Advisors was terminated, and the net profits interests in our acreage previously held by NASIF and the DJ Basin investors were canceled.

 

ENXP, LLC assigned its general partnership interest in Energy & Exploration Partners, LP to an affiliated entity of Mr. Pettit for de minimis consideration. Energy & Exploration Partners, LP is a plaintiff in certain immaterial contract disputes related to certain oil and natural gas properties previously held by us and holds no other assets. Mr. Pettit owns all of the limited partnership interests in Energy & Exploration Partners, LP.

 

Restricted Stock Awards for Management.    In connection with the transactions described above, we made awards to members of our senior management, other than Mr. Pettit, of 102,500 restricted shares of our common stock under our 2012 Stock Incentive Plan. See “Executive Compensation.”

 

In September 2012 and February 2013, Mr. Pettit contributed 22,500 and 2,500 shares, respectively, of our common stock back to us for no consideration, and we used those shares to grant restricted stock awards to certain members of our management under our 2012 Stock Incentive Plan.

 

Registration Rights Agreement.    In connection with our corporate reorganization, we entered into a registration rights agreement with all of our stockholders, including management, receiving shares of common stock in the reorganization. Pursuant to the registration rights agreement, these stockholders have demand and piggyback registration rights under which we are required to use our reasonable best efforts to register the resale of shares of our common stock held by these stockholders or their permitted transferees under certain circumstances at our expense following a qualified public offering (defined in the same manner as such term is defined for the convertible notes). We amended the agreement in connection with the issuance of warrants to Highbridge and Apollo as described below to add Highbridge and Apollo as parties to the agreement and to grant them and their permitted transferees registration rights under the agreement, and further amended the agreement in connection with the offering of the convertible notes to make certain conforming changes.

 

Certain Transactions with Highbridge and Apollo

 

In April 2013, December 2013, January 2014 and March 2014, we issued to Highbridge and Apollo senior unsecured notes with principal amounts of $140 million, $25 million, $15 million and $45 million, respectively, for a total principal amount of senior unsecured notes issued of $225 million. In July 2012, we refinanced and

 

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replaced the senior secured notes, including a prepayment premium of approximately $52.6 million, with the net proceeds of our senior secured term loan and the issuance of our convertible notes.

 

In connection with the issuance of our senior unsecured notes in April 2013, we issued to Highbridge and Apollo warrants to purchase an aggregate of 269,231 shares of our mandatorily convertible preferred stock at an exercise price of $0.01 per share. In connection with the issuance of senior unsecured notes in March 2014, we issued to Highbridge and Apollo additional warrants to purchase an aggregate of 71,122 shares of our mandatorily convertible preferred stock at an exercise price of $0.01 per share. In July 2014, we amended the terms of certain of the warrants held by Highbridge to provide for the cash settlement of those warrants, as described under “Description of Capital Stock—Preferred Stock and Warrants to Purchase Preferred Stock.”

 

In August 2013, we entered into an agreement with Highbridge and Apollo for a $75 million senior secured term loan with funding subject to certain conditions, although we did not incur any borrowings under such term loan, which was terminated on July 22, 2014.

 

Highbridge and Apollo purchased an aggregate of $25 million of our convertible notes in the offering of the convertible notes on July 22, 2014. Additionally, Highbridge and Apollo are lenders under our senior secured term loan with respect to $70 million aggregate principal amount of the senior secured term loan.

 

For additional information regarding our senior unsecured notes, the warrants issued to Highbridge and Apollo, our convertible notes and our senior secured term loan, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Debt Facilities and Notes” and “Description of Capital Stock.”

 

Joint Investment in Well Development

 

On December 1, 2013, we entered into a joint operating agreement with Energy & Exploration Partners, LP for the purpose of developing two East Texas stacked play wells, the Su-Ling #1 and the Bonanza #1H. Energy & Exploration Partners, LP invested $200,000 in Su-Ling #1 and $400,000 in Bonanza #1H, with its working interest percentage in each well equal to the amount of the respective investment divided by the drilling and completion cost for the well. B. Hunt Pettit, our President, Chief Executive Officer and director is also the sole limited partner of Energy & Exploration Partners, LP and the sole member of its general partner, Septa Holdings LLC. Prior to entering into the joint operating agreement with Energy & Exploration Partners, LP, our board of directors approved the transaction with a view that there would be no further joint investments in operations with any of our officers, directors or employees.

 

Overriding Royalty Interests

 

In August 2012, we completed the granting of overriding royalty interests in our acreage to our executive officers, including the named executive officers, certain other members of management, the limited partners of NASIF and the DJ Basin investors. These overriding royalty interests entitle the holders to receive percentages of the net revenue associated with sales of oil and natural gas produced from our acreage, with no corresponding responsibility for payment of any expenses. These percentages range from 0% to 2.5% in the East Texas stacked play, 0% to 2.2% in the Permian and 0% to 4.2% in the DJ Basin. As described under “—Corporate Reorganization,” the limited partners of NASIF and the DJ Basin investors received overriding royalty interests in connection with our corporate reorganization. Oso + Toro (as defined under “Principal and Selling Stockholders”) received overriding royalty interests ranging from 0% to 0.85% and 0% to 0.57%, respectively. Since October 2012, we have not granted, and we do not intend to grant, additional overriding royalty interests with respect to our properties to our directors, executive officers or other employees.

 

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Procedures for Approval of Related Person Transactions

 

A “related party transaction” is a transaction, arrangement or relationship in which we or any of our subsidiaries was, is or will be a participant, the amount of which involved exceeded or exceeds $120,000, and in which any related person had, has or will have a direct or indirect material interest. A “related person” means:

 

   

any person who is, or at any time during the applicable period was, one of our executive officers, directors or director nominees;

 

   

any person who is known by us to be the beneficial owner of more than 5.0% of our outstanding common stock;

 

   

any immediate family member of any of the foregoing persons, which means any child, stepchild, parent, stepparent, spouse, sibling, mother-in-law, father-in-law, son-in-law, daughter-in-law, brother-in-law or sister-in-law, or any person (other than a tenant or employee) sharing the household; and

 

   

any firm, corporation or other entity in which any of the foregoing persons is a partner or principal or in a similar position or in which such person has a 10.0% or greater beneficial ownership interest.

 

We expect that our board of directors will adopt a written related party transactions policy prior to the completion of this offering. Pursuant to this policy, we expect that the audit committee will review all material facts of all related party transactions and either approve or disapprove entry into the related party transaction, subject to certain limited exceptions. We anticipate that the policy will provide that, in determining whether to approve or disapprove entry into a related party transaction, the audit committee shall take into account, among other factors, the following: (1) whether the related party transaction is on terms no less favorable than terms generally available to an unaffiliated third-party under the same or similar circumstances and (2) the extent of the related person’s interest in the transaction. Further, we expect the policy to require that all related party transactions required to be disclosed in our filings with the SEC be so disclosed in accordance with applicable laws, rules and regulations.

 

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PRINCIPAL AND SELLING STOCKHOLDERS

 

The table below sets forth information regarding the beneficial ownership of the common stock of Energy & Exploration Partners, Inc. as of August 31, 2014 by (1) each beneficial owner of more than 5% of our outstanding common stock, (2) each director of Energy & Exploration Partners, Inc., (3) each of our named executive officers, and (4) all executive officers and directors as a group. The table also sets forth information regarding the shares of common stock that will be sold by the selling stockholders in this offering. As of August 31, 2014, there were                 shares of our common stock outstanding, giving effect to the     -for-1 stock split that will be effected immediately prior to completion of this offering, and we had outstanding warrants to purchase 340,353 shares of our mandatorily convertible preferred stock that, upon exercise of the warrants, would be convertible into             shares of our common stock. Additionally, our convertible notes will be convertible at the option of the holders thereof into an aggregate of             shares of our common stock upon the consummation of this offering assuming an initial public offering price per share of $         in this offering, and we expect that all such holders will convert their convertible notes. The ownership percentages after the offering are based on the issuance and sale by us of             shares of common stock in the offering, assuming no exercise of the underwriters’ option to purchase additional shares, and the sale by the selling stockholders of              shares of common stock in this offering. After the offering and the automatic exercise of outstanding warrants for shares of our common stock at the completion of this offering on a net basis assuming an initial public offering price of $         per share and the conversion of all outstanding convertible notes assuming an initial public offering price of $         per             share, there will be             shares of our common stock outstanding.

 

Beneficial ownership is determined in accordance with the rules of the SEC and includes voting or investment power with respect to the securities. Except as indicated by footnote, to our knowledge the persons named in the table below have sole voting and investment power with respect to all common stock shown as beneficially owned by them, subject to community property laws where applicable. Unless otherwise indicated, the address for each stockholder, director and executive officer listed is: Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, Texas 76102.

 

Name of Beneficial Owner

   Shares of
Common Stock
Beneficially Owned
Prior to this Offering
    Shares
Offered
Pursuant
to this
Prospectus
   Shares of
Common Stock
Beneficially Owned
After this Offering
   Number    Percentage        Number    Percentage

Selling Stockholders

             
             
             
             
             
             
             
             
             
             
             
             
             

Directors and Named Executive Officers

             

B. Hunt Pettit(1)

        47.30        

Don Dimitrievich(2)

        —             

Brian C. Nelson

        9.79        

Tom D. McNutt(3)

        4.71        

 

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Name of Beneficial Owner

   Shares of
Common Stock
Beneficially Owned
Prior to this Offering
    Shares
Offered
Pursuant
to this
Prospectus
   Shares of
Common Stock
Beneficially Owned
After this Offering
   Number    Percentage        Number    Percentage

All directors and executive officers as a group

             

(8 persons)

        70.71        

Other 5% Holders

             

Oso + Toro(4)

        18.48        

Highbridge(5)

        30.00        

Apollo(6)

        19.23        

 

*   Less than 1%
(1)   Includes             shares held by trusts for the benefit of Mr. Pettit and his spouse and children over which Mr. Pettit has sole voting power and dispositive power as sole trustee, and             shares owned by H Pettit HC, Inc. of which Mr. Pettit is the sole stockholder, President and Secretary and sole director.
(2)   Mr. Dimitrievch’s address is 40 West 57th Street, 33rd Floor, New York, New York 10019.
(3)   Includes             shares held by trusts over which Mr. McNutt has sole voting power and dispositive power as sole trustee. Mr. McNutt has no beneficial interest in these trusts.
(4)   Consists of             shares owned by Oso + Toro Multi Strategy Fund Series Interests of the SALI Multi-Series Fund II 3(c)(1), L.P. and             shares owned by Oso + Toro Multi Strategy Fund (Tax Exempt) Segregated Portfolio of SALI Multi-Series Fund SPC, Ltd. The business address is 6836 Austin Center Boulevard, Suite 320, Austin, Texas 78731. Tom Nieman, the Chief Financial Officer of SALI Fund Management, LLC, the Investment Manager, and Justin Pawl, Partner and Managing Director of Covenant Multi Family Offices, LLC, the Investment Subadvisor, exercise joint voting and investment power with respect to the shares of our common stock owned by such entities.
(5)   Consists of             shares issuable upon conversion of shares of preferred stock issuable upon exercise of warrants owned by Highbridge Principal Strategies—Mezzanine Partners II Delaware Subsidiary, LLC, shares issuable upon conversion of shares of preferred stock issuable upon exercise of warrants owned by Highbridge Principal Strategies—AP Mezzanine Partners II, L.P.,             shares issuable upon conversion of shares of preferred stock issuable upon exercise of warrants owned by ENXP Offshore, L.P., and             shares issuable upon conversion of shares of preferred stock issuable upon exercise of warrants owned by ENXP Institutional, L.P. The business address is 40 West 57th Street, 33rd Floor, New York, New York 10019. The Highbridge Mezzanine Fund Investment Committee, comprised of Scott Kapnick, Scot French, Michael Patterson, Purnima Puri and Faith Rosenfeld, exercises voting and investment power with respect to the shares of our common stock owned by such entities.
(6)   Consists of             shares issuable upon conversion of shares of preferred stock issuable upon exercise of warrants owned by Apollo Investment Corporation,             shares issuable upon conversion of shares of preferred stock issuable upon exercise of warrants owned by Apollo Special Opportunities Managed Account, L.P.,             shares issuable upon conversion of shares of preferred stock issuable upon exercise of warrants owned by Apollo Centre Street Partnership, L.P., and             shares owned by ANS U.S. Holdings Ltd. The business address is c/o Apollo Management, L.P., 9 W 57th Street, New York, New York 10019. Joseph Glatt, Vice President of Apollo, exercises voting and investment power with respect to the shares of our common stock owned by such entities.

 

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DESCRIPTION OF CAPITAL STOCK

 

Upon completion of this offering, the authorized capital stock of Energy & Exploration Partners, Inc. will consist of             shares of common stock, $0.01 par value per share, of which             shares will be issued and outstanding, and             shares of preferred stock, $0.01 par value per share, of which no shares will be issued and outstanding.

 

The following description includes summaries of the material terms and provisions of our amended and restated certificate of incorporation and amended and restated bylaws. This description is qualified by reference to our amended and restated certificate of incorporation and amended and restated bylaws, which will be filed as exhibits to the registration statement of which this prospectus is a part, and to the provisions of applicable law.

 

Common Stock

 

Except as provided by law or in a preferred stock designation, holders of common stock are entitled to one vote for each share held of record on all matters submitted to a vote of the stockholders, will have the exclusive right to vote for the election of directors and do not have cumulative voting rights. Except as otherwise required by law, holders of common stock, as such, are not entitled to vote on any amendment to the certificate of incorporation (including any certificate of designations relating to any series of preferred stock) that relates solely to the terms of any outstanding series of preferred stock if the holders of such affected series are entitled, either separately or together with the holders of one or more other such series, to vote thereon pursuant to the amended and restated certificate of incorporation (including any certificate of designations relating to any series of preferred stock) or pursuant to the General Corporation Law of the State of Delaware. Subject to preferences that may be applicable to any outstanding shares or series of preferred stock, holders of common stock are entitled to receive ratably such dividends (payable in cash, stock or otherwise), if any, as may be declared from time to time by our board of directors out of funds legally available for dividend payments. All outstanding shares of common stock are fully paid and non-assessable, and the shares of common stock to be issued upon completion of this offering will be fully paid and non-assessable. The holders of common stock have no preferences or rights of conversion, exchange, pre-emption or other subscription rights. There are no redemption or sinking fund provisions applicable to the common stock. In the event of any liquidation, dissolution or winding-up of our affairs, holders of common stock will be entitled to share ratably in our assets that are remaining after payment or provision for payment of all of our debts and obligations and after liquidation payments to holders of outstanding shares of preferred stock, if any.

 

Preferred Stock and Warrants to Purchase Preferred Stock

 

Our amended and restated certificate of incorporation will authorize our board of directors, subject to any limitations prescribed by law, without further stockholder approval, to establish and to issue from time to time one or more classes or series of preferred stock, par value $0.01 per share, covering up to an aggregate of                 shares of preferred stock. Each class or series of preferred stock will cover the number of shares and will have the powers, preferences, rights, qualifications, limitations and restrictions determined by the board of directors, which may include, among others, dividend rights, liquidation preferences, voting rights, conversion rights, preemptive rights and redemption rights. Except as provided by law or in a preferred stock designation, the holders of preferred stock will not be entitled to vote at or receive notice of any meeting of stockholders.

 

In April 2013, we created two new series of our preferred stock, each with a par value of $0.01 per share, designated as the “Series A Mandatorily Convertible Preferred Stock” and the “Series B Mandatorily Convertible Preferred Stock.” In connection with the issuance of our senior unsecured notes in April 2013, we issued to Highbridge and Apollo warrants to purchase an aggregate of 269,231 shares of our Series A Mandatorily Convertible Preferred Stock and Series B Mandatorily Convertible Preferred Stock at an exercise price of $0.01 per share. In connection with the issuance of senior unsecured notes in March 2014, we issued to Highbridge and Apollo additional warrants to purchase an aggregate of 71,122 shares of our Series A Mandatorily Convertible

 

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Preferred Stock and Series B Mandatorily Convertible Preferred Stock at an exercise price of $0.01. Each share of the preferred stock is convertible at the option of the holder prior to a qualified public offering (defined in the same manner as such term is defined for the convertible notes ) and will convert automatically upon completion of a qualified public offering into             shares of our common stock, or an aggregate of             shares of our common stock. To the extent not previously exercised, at the completion of a qualified public offering, the warrants will automatically convert on a net basis into the number shares of our common stock into which the shares of preferred stock issuable upon exercise of the warrants would then be converted, less a number of shares equal to the aggregate exercise price divided by the initial public offering per share.

 

No shares of preferred stock will be outstanding upon completion of this offering.

 

Anti-Takeover Effects of Provisions of Our Certificate of Incorporation, Our Bylaws and Delaware Law

 

Some provisions of Delaware law and our amended and restated certificate of incorporation and our amended and restated bylaws, will contain provisions that could make the following transactions more difficult: acquisitions of us by means of a tender offer, a proxy contest or otherwise; or removal of our incumbent directors. These provisions may also have the effect of preventing changes in our management. It is possible that these provisions could make it more difficult to accomplish or could deter transactions that stockholders may otherwise consider to be in their best interest or in our best interests, including transactions that might result in a premium over the market price for our shares.

 

These provisions, summarized below, are expected to discourage coercive takeover practices and inadequate takeover bids. These provisions are also designed to encourage persons seeking to acquire control of us to first negotiate with us. We believe that the benefits of increased protection and our potential ability to negotiate with the proponent of an unfriendly or unsolicited proposal to acquire or restructure us outweigh the disadvantages of discouraging these proposals because, among other things, negotiation of these proposals could result in an improvement of their terms.

 

Section 203 of the Delaware General Corporation Law

 

We will be subject to the provisions of Section 203 of the General Corporation Law of the State of Delaware (“DGCL”) regulating corporate takeovers. In general, those provisions prohibit a Delaware corporation, including those whose securities are listed for trading on the NYSE, from engaging in any business combination with any interested stockholder for a period of three years following the date that the stockholder became an interested stockholder, unless:

 

   

the transaction is approved by the board of directors before the date the interested stockholder attained that status;

 

   

upon consummation of the transaction that resulted in the stockholder becoming an interested stockholder, the interested stockholder owned at least 85% of the voting stock of the corporation outstanding at the time the transaction commenced; or

 

   

on or after such time the business combination is approved by the board of directors and authorized at a meeting of stockholders by at least two-thirds of the outstanding voting stock that is not owned by the interested stockholder.

 

Section 203 defines “business combination” to include the following:

 

   

any merger or consolidation involving the corporation and the interested stockholder;

 

   

any sale, transfer, pledge or other disposition of 10% or more of the assets of the corporation involving the interested stockholder;

 

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subject to certain exceptions, any transaction that results in the issuance or transfer by the corporation of any stock of the corporation to the interested stockholder;

 

   

any transaction involving the corporation that has the effect of increasing the proportionate share of the stock of any class or series of the corporation beneficially owned by the interested stockholder; or

 

   

the receipt by the interested stockholder of the benefit of any loans, advances, guarantees, pledges or other financial benefits provided by or through the corporation.

 

In general, Section 203 defines an interested stockholder as any entity or person beneficially owning 15% or more of the outstanding voting stock of the corporation and any entity or person affiliated with or controlling or controlled by any of these entities or persons.

 

A Delaware corporation may “opt out” of Section 203 with an express provision in its original certificate of incorporation or an express provision in its certificate of incorporation or bylaws resulting from amendments approved by the holders of at least a majority of the corporation’s outstanding voting shares. We do not intend to “opt out” of the provisions of Section 203. The statute could prohibit or delay mergers or other takeover or change in control attempts and, accordingly, may discourage attempts to acquire us.

 

Amended and Restated Certificate of Incorporation and Amended and Restated Bylaws

 

Among other things, upon the completion of this offering, our amended and restated certificate of incorporation and amended and restated bylaws will:

 

   

establish advance notice procedures with regard to stockholder proposals relating to the nomination of candidates for election as directors or new business to be brought before meetings of our stockholders. These procedures provide that notice of stockholder proposals must be timely given in writing to our corporate secretary prior to the meeting at which the action is to be taken. Generally, to be timely, notice must be received at our principal executive offices not less than 90 days nor more than 120 days prior to the first anniversary date of the annual meeting for the preceding year. Our amended and restated bylaws specify the requirements as to form and content of all stockholders’ notices. These requirements may preclude stockholders from bringing matters before the stockholders at an annual or special meeting;

 

   

provide our board of directors the ability to authorize undesignated preferred stock. This ability makes it possible for our board of directors to issue, without stockholder approval, preferred stock with voting or other rights or preferences that could impede the success of any attempt to change control of us. These and other provisions may have the effect of deferring hostile takeovers or delaying changes in control or management of our company;

 

   

provide that the authorized number of directors may be changed only by resolution of the board of directors;

 

   

provide that all vacancies, including newly created directorships, may, except as otherwise required by law, be filled by the affirmative vote of a majority of directors then in office, even if less than a quorum;

 

   

provide that any action required or permitted to be taken by the stockholders must be effected at a duly called annual or special meeting of stockholders and may not be effected by any consent in writing in lieu of a meeting of such stockholders, subject to the rights of the holders of any series of preferred stock;

 

   

provide that our certificate of incorporation and bylaws may be amended by the affirmative vote of the holders of at least two-thirds of our then outstanding common stock; and

 

   

provide that special meetings of our stockholders may only be called by the board of directors, the chief executive officer or the chairman of the board;

 

   

provide for our board of directors to be divided into three classes of directors, with each class as nearly equal in number as possible, serving staggered three year terms, other than directors who may be elected

 

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by holders of preferred stock, if any. For more information on the classified board of directors, please see “Management.” This system of electing and removing directors may tend to discourage a third party from making a tender offer or otherwise attempting to obtain control of us, because it generally makes it more difficult for stockholders to replace a majority of the directors; and

 

   

provide that our bylaws can be amended or repealed at any regular or special meeting of stockholders or by the board of directors.

 

Limitation of Liability and Indemnification Matters

 

Our amended and restated certificate of incorporation will limit the liability of our directors for monetary damages for breach of their fiduciary duty as directors, except for liability that cannot be eliminated under the DGCL. Delaware law provides that directors of a company will not be personally liable for monetary damages for breach of their fiduciary duty as directors, except for liabilities:

 

   

for any breach of their duty of loyalty to us or our stockholders;

 

   

for acts or omissions not in good faith or that involve intentional misconduct or a knowing violation of law;

 

   

for unlawful payment of dividend or unlawful stock repurchase or redemption, as provided under Section 174 of the DGCL; or

 

   

for any transaction from which the director derived an improper personal benefit.

 

Any amendment, repeal or modification of these provisions will be prospective only and would not affect any limitation on liability of a director for acts or omissions that occurred prior to any such amendment, repeal or modification.

 

Our amended and restated certificate of incorporation and amended and restated bylaws will also provide that we will indemnify our directors and officers to the fullest extent permitted by Delaware law. Our amended and restated bylaws will also permit us to purchase insurance on behalf of any officer, director, employee or other agent for any liability arising out of that person’s actions as our officer, director, employee or agent, regardless of whether Delaware law would permit indemnification. We intend to enter into indemnification agreements with each of our current and future directors and officers. These agreements will require us to indemnify these individuals to the fullest extent permitted under Delaware law against liability that may arise by reason of their service to us, and to advance expenses incurred as a result of any proceeding against them as to which they could be indemnified. We believe that the limitation of liability provision in our amended and restated certificate of incorporation and the indemnification agreements will facilitate our ability to continue to attract and retain qualified individuals to serve as directors and officers.

 

Choice of Forum

 

Our amended and restated certificate of incorporation will provide that unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware will be the sole and exclusive forum for:

 

   

any derivative action or proceeding brought on our behalf;

 

   

any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees or agents to us or our stockholders;

 

   

any action asserting a claim against us or any director or officer or other employee of ours arising pursuant to any provision of the DGCL or our amended and restated certificate of incorporation or bylaws; or

 

   

any action asserting a claim against us or any director or officer or other employee of ours governed by the internal affairs doctrine.

 

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Our amended and restated certificate of incorporation will also provide that any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock will be deemed to have notice of and to have consented to this choice of forum provision. It is possible that a court of law could rule that the choice of forum provision contained in our amended and restated certificate of incorporation is inapplicable or unenforceable if it is challenged in a proceeding or otherwise.

 

Transfer Agent and Registrar

 

We have appointed Computershare Trust Company, N.A. as the transfer agent and registrar for our common stock.

 

Listing

 

We have applied to list our common stock on the New York Stock Exchange under the symbol “ENXP.”

 

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SHARES ELIGIBLE FOR FUTURE SALE

 

Prior to this offering, there has been no public market for our common stock. Future sales of our common stock in the public market, or the availability of such shares for sale in the public market, could adversely affect market prices prevailing from time to time. As described below, only a limited number of shares, other than shares sold in this offering, will be available for sale shortly after this offering due to contractual and legal restrictions on resale. Nevertheless, sales of a substantial number of shares of our common stock in the public market after such restrictions lapse, or the perception that those sales may occur, could adversely affect the prevailing market price at such time and our ability to raise equity-related capital at a time and price we deem appropriate.

 

Sales of Restricted Shares

 

Upon the closing of this offering, we will have issued and outstanding an aggregate of             shares of common stock. Of these shares, all of the             shares of common stock to be sold in this offering will be freely tradable without restriction or further registration under the Securities Act, unless the shares are held by any of our “affiliates” as such term is defined in Rule 144 under the Securities Act. All remaining shares of common stock held by existing stockholders will be deemed “restricted securities” as such term is defined in Rule 144. The restricted securities were issued and sold by us in private transactions and are eligible for public sale only if registered under the Securities Act or if they qualify for an exemption from registration under Rule 144 or Rule 701 under the Securities Act, which rules are summarized below.

 

Under the provisions of Rule 144 and Rule 701 under the Securities Act, all of the shares of our common stock (excluding the shares to be sold in this offering) will be available for sale in the public market upon the expiration of the lock-up agreements, beginning 180 days after the date of this prospectus (subject to certain exceptions and extensions) and when permitted under Rule 144 or Rule 701.

 

Lock-up Agreements

 

We, all of our directors and executive officers, certain of our existing stockholders and the holders of the convertible notes have agreed not to sell or otherwise transfer or dispose of any common stock for a period of 180 days from the date of this prospectus, subject to certain exceptions and extensions. See “Underwriting” for a description of these lock-up provisions.

 

Rule 144

 

In general, under Rule 144 as currently in effect, once we have been a reporting company subject to the reporting requirements of Section 13 or 15(d) of the Exchange Act for 90 days, a person (or persons whose shares are aggregated) who is not deemed to have been an affiliate of ours at any time during the three months preceding a sale, and who has beneficially owned restricted securities within the meaning of Rule 144 for at least six months (including any period of consecutive ownership of preceding non-affiliated holders) would be entitled to sell those shares, subject only to the availability of current public information about us. A non-affiliated person who has beneficially owned restricted securities within the meaning of Rule 144 for at least one year would be entitled to sell those shares without regard to the provisions of Rule 144.

 

In general, once we have been a reporting company subject to the reporting requirements of Section 13 or 15(d) of the Exchange Act for 90 days, a person (or persons whose shares are aggregated) who is deemed to be an affiliate of ours and who has beneficially owned restricted securities within the meaning of Rule 144 for at least six months would be entitled to sell within any three-month period a number of shares that does not exceed the greater of one percent of the then outstanding shares of our common stock or the average weekly trading volume of our common stock reported through the New York Stock Exchange during the four calendar weeks preceding the filing of notice of the sale. Such sales are also subject to certain manner of sale provisions, notice requirements and the availability of current public information about us.

 

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Rule 701

 

Employees, directors, officers, consultants or advisors who received shares from us in connection with a compensatory stock or option plan or other written compensatory agreement in accordance with Rule 701 before the effective date of the registration statement of which this prospectus is a part are entitled to sell such shares 90 days after the effective date of the registration statement in reliance on Rule 144 without having to comply with the holding period requirement of Rule 144 and, in the case of non-affiliates, without having to comply with the public information, volume limitation or notice filing provisions of Rule 144.

 

Stock Issued Under Employee Plans

 

We intend to file a registration statement on Form S-8 under the Securities Act to register stock issuable under our 2012 Stock Incentive Plan. This registration statement is expected to be filed following the effective date of the registration statement of which this prospectus is a part and will be effective upon filing. Accordingly, shares registered under such registration statement will be available for sale in the open market following the effective date, unless such shares are subject to vesting restrictions with us, Rule 144 restrictions applicable to our affiliates or the lock-up restrictions described above.

 

Registration Rights

 

We entered into a registration rights agreement in connection with our corporate reorganization pursuant to which we are required to use our reasonable best efforts to register the resale of shares of our common stock held by certain of our stockholders or their permitted transferees under certain circumstances at our expense. We amended the agreement in connection with the issuance of warrants to Highbridge and Apollo to add Highbridge and Apollo as parties to the agreement and to grant them and their permitted transferees registration rights under the agreement. See “Certain Relationships and Related Party Transactions—Corporate Reorganization” and “—Certain Transactions with Highbridge and Apollo.”

 

In addition, in connection with the issuance of the convertible notes, we entered into a registration rights agreement for the benefit of the holders of the convertible notes under which we are required to file a shelf registration statement that must be effective within 180 days after the closing of this this offering covering the resale of all shares of our common stock that are issued upon conversion of the convertible notes, other than the shares being sold in this offering.

 

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MATERIAL U.S. FEDERAL INCOME TAX CONSIDERATIONS FOR NON-U.S. HOLDERS

 

The following is a general discussion of the material U.S. federal income tax consequences of the acquisition, ownership and disposition of our common stock to a non-U.S. holder. For the purpose of this discussion, a non-U.S. holder is any beneficial owner of our common stock that is not for U.S. federal income tax purposes any of the following:

 

   

an individual citizen or resident of the U.S.;

 

   

a corporation (or other entity treated as a corporation for U.S. federal income tax purposes) created or organized in the U.S. or under the laws of the United States or any state or the District of Columbia;

 

   

a partnership (or other entity treated as a partnership or other pass-through entity for U.S. federal income tax purposes);

 

   

an estate whose income is subject to U.S. federal income tax regardless of its source; or

 

   

a trust (x) whose administration is subject to the primary supervision of a court within the United States and which has one or more U.S. persons (as defined for U.S. federal income tax purposes) who have the authority to control all substantial decisions of the trust or (y) which has made a valid election to be treated as a U.S. person.

 

If a partnership (or an entity treated as a partnership for U.S. federal income tax purposes) holds our common stock, the tax treatment of a partner in the partnership will generally depend on the status of the partner and upon the activities of the partnership. Accordingly, if you are treated as a partner of a partnership that holds our common stock you should consult your own tax advisor as to the particular U.S. federal income taxes applicable to you.

 

This discussion assumes that a non-U.S. holder will hold our common stock issued pursuant to the offering as a capital asset (generally, property held for investment) within the meaning of Section 1221 of the Internal Revenue Code of 1986, as amended (the “Code”). This discussion does not address all aspects of U.S. federal taxation (including alternative minimum, gift and estate tax) or any other U.S. federal tax laws, including Medicare taxes imposed on net investment income or any aspects of state, local or non-U.S. taxation. It does not consider any U.S. federal income tax considerations that may be relevant to non-U.S. holders that may be subject to special treatment under U.S. federal income tax laws, including, without limitation, U.S. expatriates, life insurance companies, tax-exempt or governmental organizations, dealers in securities or currency, banks or other financial institutions, investors whose functional currency is other than the U.S. dollar, “passive foreign investment companies,” “controlled foreign corporations,” persons who at any time hold more than 5% of the fair market value of any class of our stock and investors that hold our common stock as part of a hedge, straddle or conversion transaction. Furthermore, the following discussion is based on current provisions of the Code, Treasury Regulations and administrative and judicial interpretations thereof, all as in effect on the date hereof, and all of which are subject to change, possibly with retroactive effect.

 

We urge each prospective investor to consult a tax advisor regarding the U.S. federal, state, local and non-U.S. income and other tax consequences of acquiring, holding and disposing of shares of our common stock.

 

Distributions

 

We do not plan to make any distributions for the foreseeable future. However, if we do make distributions on our common stock, those payments will constitute dividends to the extent paid from our current or accumulated earnings and profits, as determined under U.S. federal income tax principles. To the extent those distributions exceed our current and accumulated earnings and profits, the distributions will first reduce a non-U.S. holder’s adjusted tax basis in the common stock (determined on a share by share basis), but not below zero, and then will be treated as gain from the sale of the common stock (subject to the rules discussed below under “—Gain on Disposition of Common Stock”).

 

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Any dividends (out of earnings and profits) paid to a non-U.S. holder of our common stock that are not effectively connected with a U.S. trade or business conducted by the non-U.S. holder generally will be subject to U.S. withholding tax either at a rate of 30% of the gross amount of the dividend or such lower rate as may be specified by an applicable tax treaty. To receive the benefit of a reduced treaty rate, a non-U.S. holder must provide us or our paying agent with a valid Internal Revenue Service (“IRS”) Form W-8BEN-E or other appropriate version of IRS Form W-8 certifying qualification for the reduced rate.

 

Dividends received by a non-U.S. holder that are effectively connected with a U.S. trade or business conducted by the non-U.S. holder (and if a treaty applies, are attributable to a U.S. permanent establishment of such non-U.S. holder) are exempt from such U.S. withholding tax. To obtain this exemption, the non-U.S. holder must provide us or our paying agent with a valid IRS Form W-8ECI properly certifying such exemption. Such effectively connected dividends, although not subject to withholding tax, will be subject to U.S. federal income tax on a net income basis at the same graduated rates generally applicable to U.S. persons, subject to any applicable tax treaty providing otherwise. In addition to the income tax described above, dividends received by corporate non-U.S. holders that are effectively connected with a U.S. trade or business of the corporate non-U.S. holder may be subject to a branch profits tax at a rate of 30% (or such lower rate as may be specified by an applicable tax treaty).

 

A non-U.S. holder of our common stock may obtain a refund of any excess amounts withheld if the non-U.S. holder is eligible for a reduced rate of U.S. withholding tax and an appropriate claim for refund is timely filed with the IRS.

 

Gain on Disposition of Common Stock

 

Subject to the discussion of backup withholding, below, a non-U.S. holder generally will not be subject to U.S. federal income tax on any gain realized upon the sale or other disposition of our common stock unless:

 

   

the gain is effectively connected with a U.S. trade or business of the non-U.S. holder and, if required by an applicable tax treaty, is attributable to a U.S. permanent establishment maintained by such non-U.S. holder;

 

   

the non-U.S. holder is an individual who is present in the United States for a period or periods aggregating 183 days or more during the calendar year in which the sale or disposition occurs and certain other conditions are met; or

 

   

our common stock constitutes a “U.S. real property interest” by reason of our status as a U.S. real property holding corporation (a “USRPHC”) for U.S. federal income tax purposes at any time within the shorter of the five-year period preceding the disposition or the non-U.S. holder’s holding period for our common stock.

 

Unless an applicable tax treaty provides otherwise, gain described in the first bullet point above will be recognized in an amount equal to the excess of the amount of cash and the fair market value of any other property received for the common stock over the non-U.S. holder’s basis in the common stock. Such gain or loss will be generally subject to U.S. federal income tax on a net income basis at the same graduated rates generally applicable to U.S. persons. In the case of a non-U.S. holder that is a foreign corporation, such gain may also be subject to a branch profits tax at a rate of 30% (or such lower rate as may be specified by an applicable tax treaty).

 

Gain described in the second bullet point above (which may be offset by U.S. source capital losses, provided that the non-U.S. holder has timely filed U.S. federal income tax returns with respect to such losses) will be subject to a flat 30% U.S. federal income tax (or such lower rate as may be specified by an applicable tax treaty).

 

With respect to the third bullet point above, we believe we are, and will remain for the foreseeable future, a USRPHC. If we are so classified, gain arising from the sale or other taxable disposition by a non-U.S. holder of our common stock will not be subject to tax if such class of stock is regularly traded on an established securities market, as defined by applicable Treasury Regulations, and such non-U.S. holder does not own, actually or

 

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constructively, more than 5% of such class of our stock at any time during the shorter of the five-year period ending on the date of the sale or exchange or the non-U.S. holder’s holding period for our common stock. We expect our common stock to be regularly traded on an established securities market, although we cannot guarantee it will be so traded. If gain on the sale or other taxable disposition of our stock were subject to taxation under the third bullet point above, the non-U.S. holder would be subject to regular U.S. federal income tax with respect to such gain in generally the same manner as a U.S. person and would have to file a U.S. income tax return reporting such gain or loss.

 

Non-U.S. holders should consult a tax advisor regarding potentially applicable income tax treaties that may provide for different rules.

 

Backup Withholding and Information Reporting

 

Generally, we must report annually to the IRS the amount of dividends paid to each non-U.S. holder, the name and address of the recipient, and the amount, if any, of tax withheld with respect to those dividends. A similar report is sent to each non-U.S. holder. These information reporting requirements apply regardless of whether withholding was reduced or eliminated. This information also may be made available under a specific treaty or agreement with the tax authorities of the country in which the non-U.S. holder resides or is established. Payment of the proceeds of a sale of our common stock within the United States or through certain U.S. financial intermediaries is also subject to information reporting, and depending on the circumstances may be subject to backup withholding unless the non-U.S. holder, certifies that it is a non-U.S. holder or furnishes an IRS Form W-8.

 

Payments of dividends to a non-U.S. holder may be subject to backup withholding (at the applicable rate) unless the non-U.S. holder establishes an exemption, for example, by properly certifying its non-U.S. status on an IRS Form W-8BEN-E or another appropriate version of IRS Form W-8. Notwithstanding the foregoing, backup withholding may apply if either we or our paying agent has actual knowledge, or reason to know, that the beneficial owner is a U.S. person that is not an exempt recipient.

 

Backup withholding is not an additional tax. Any amounts withheld under the backup withholding rules may be claimed as a refund or a credit against a non-U.S. holder’s U.S. federal income tax liability, provided that the required information is timely furnished to the IRS. Non-U.S. holders should consult their own tax advisors regarding the application of backup withholding in their particular circumstances and the availability of, and procedures for, obtaining an exemption from backup withholding.

 

Additional Withholding Tax Relating to Foreign Accounts

 

After June 30, 2014, withholding at a rate of 30% will generally be required on dividends in respect of, and, after December 31, 2016, gross proceeds from the sale or other disposition of, our common stock held by or through certain foreign financial institutions (including investment funds), unless such institution enters into an agreement with the IRS to report, on an annual basis, information with respect to shares in, and accounts maintained by, the institution to the extent such shares or accounts are held by certain United States persons or by certain non-U.S. entities that are wholly or partially owned by United States persons and to withhold on certain payments. An intergovernmental agreement between the United States and an applicable foreign country, or future United States Treasury regulations, may modify these requirements. Accordingly, the entity through which our common stock is held will affect the determination of whether such withholding is required. Similarly, dividends in respect of, and gross proceeds from the sale of, our common stock held by an investor that is a non-financial non-U.S. entity that does not qualify under certain exemptions will be subject to withholding at a rate of 30%, unless such entity either (i) certifies to us that such entity does not have any “substantial United States owners” or (ii) provides certain information regarding the entity’s “substantial United States owners,” which we will in turn provide to the IRS. We will not pay any additional amounts to holders in respect of any amounts withheld. Non-U.S. holders are encouraged to consult their tax advisors regarding the possible implications of these provisions on their investment in our common stock.

 

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UNDERWRITING

 

Citigroup Global Markets Inc. and Credit Suisse Securities (USA) LLC are acting as joint book-running managers of this offering and as representative of each of the underwriters named below. Subject to the terms and conditions set forth in an underwriting agreement among us, the selling stockholders and the representative, we and the selling stockholders have agreed to sell to the underwriters, and each of the underwriters has agreed, severally and not jointly, to purchase from us and the selling stockholders, the number of shares of common stock set forth opposite its name below.

 

Underwriter

   Number
of Shares

Citigroup Global Markets Inc.

  

Credit Suisse Securities (USA) LLC

  

RBC Capital Markets, LLC

  
  

 

Total

  
  

 

 

Subject to the terms and conditions set forth in the underwriting agreement, the underwriters have agreed, severally and not jointly, to purchase all of the shares sold under the underwriting agreement if any of these shares are purchased, other than the shares covered by the option described below unless and until this option is exercised.

 

We and the selling stockholders have agreed to indemnify the underwriters against certain liabilities, including liabilities under the Securities Act, and to contribute to payments the underwriters may be required to make for certain liabilities.

 

The underwriters are offering the shares, subject to prior sale, when, as and if issued to and accepted by them, subject to approval of legal matters by their counsel, including the validity of the shares, and other conditions contained in the underwriting agreement, such as the receipt by the underwriters of officer’s certificates and legal opinions. The underwriters reserve the right to withdraw, cancel or modify offers to the public and to reject orders in whole or in part.

 

Commissions and Discounts

 

The underwriters have advised us and the selling stockholders that they propose to offer the shares of common stock directly to the public at the public offering price set forth on the cover page of this prospectus and to dealers at the public offering price less a selling concession not in excess of $         per share. The underwriters also may allow, and dealers may reallow, a concession not in excess of $         per share to brokers and dealers. After the offering, the underwriters may change the offering price and the other selling terms.

 

The following table shows the public offering price, underwriting discount and proceeds before expenses to us and the proceeds to the selling stockholders. The information assumes either no exercise or full exercise by the underwriters of their option to purchase additional shares.

 

     Per
Share
   Without
Over-allotment
Exercise
   With
Over-allotment
Exercise

Public offering price

        

Underwriting discount paid by us

        

Underwriting discount paid by selling stockholders

        

Proceeds, before expenses, to us

        

Proceeds to selling stockholders

        

 

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In addition to the underwriting discounts and commissions to be paid by us, we have agreed to reimburse the underwriters for certain of their out-of-pocket expenses incurred in connection with this offering, including travel, legal, document production and distribution and database and research expenses and the reasonable fees and disbursements of underwriters’ independent counsel, which we estimate to be approximately $         million. We estimate that the total expenses of the offering payable by us, including compensation paid to the underwriters other than underwriting discounts and commissions, will be approximately $         million.

 

Option to Purchase Additional Shares

 

We have granted to the underwriters an option to purchase up to an aggregate of             additional shares of common stock at the public offering price less the underwriting discount. The underwriters may exercise this option solely for the purpose of covering over-allotments, if any, made in connection with the offering of the shares of common stock offered by this prospectus. The underwriters may exercise that option for 30 days. If any shares are purchased pursuant to this option, the underwriters will severally purchase shares in approximately the same proportion as set forth in the table above.

 

Lock-Up Agreements

 

We, each of our executive officers and directors and certain of our existing stockholders (including the selling stockholders) have agreed not to do any of the following, directly or indirectly, for 180 days after the date of this prospectus without the prior written consent of the representative (regardless whether the transactions described in the first two bullet points are settled in securities, cash or otherwise):

 

   

offer, pledge, sell, contract to sell, sell any option or contract to purchase, purchase any option or contract to sell, grant any option, right or warrant to purchase, lend or otherwise transfer or dispose of any shares of our common stock, preferred stock or other capital stock, or any options or warrants to purchase any shares of our common stock, preferred stock or other capital stock, or any securities convertible into, exchangeable for or that represent the right to receive shares of our common stock, preferred stock or other capital stock, whether now owned or later acquired or owned directly or beneficially by the stockholder (including holding as a custodian);

 

   

engage in any hedging or other transaction that is designed to or reasonably expected to lead to, or result in, a sale or disposition of such securities (such prohibited hedging or other transactions includes any short sale (whether or not against the box) or any purchase, sale or grant of any right (including any put or call option or any swap or other arrangements that transfers to another, in whole or in part, directly or indirectly, any of the economic consequences of ownership of such securities) with respect to any of such securities or with respect to any security that includes, relates to, or derives any significant part of its value from such securities); and

 

   

file or cause the filing of any registration statement with respect to any of our common stock, preferred stock or other capital stock or any securities convertible into or exercisable or exchangeable for any of our common stock, preferred stock or other capital stock, other than certain registration statements filed to register securities to be sold to the underwriters pursuant to the underwriting agreement and to register common stock to be issued pursuant to certain of our stock compensation plans.

 

The restrictions described above do not apply to (1) the issuance of common stock by us to the underwriters pursuant to this offering, (2) the issuance of restricted stock by us in the ordinary course of business pursuant to our 2012 Stock Incentive Plan, (3) the issuance of shares of common stock by us upon the exercise of certain outstanding options, (4) bona fide gifts, other than by us, or transfers by will or intestacy, (5) transfers, other than by us, to any trust for the direct or indirect benefit of the stockholder or the immediate family of the stockholder and (6) transfers, other than by us, to limited partners or stockholders of the stockholder. In the case of (3), (4) and (5) above, (a) the transferee must deliver a signed lock-up agreement for the balance of the 180-day period, (b) the transfer must not involve a disposition for value, (c) the transfer must not be publicly reportable under any law and (d) the stockholder must not otherwise voluntarily effect any public filing, report or announcement regarding such transfer.

 

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If (1) during the last 17 days of the 180-day period, we issue an earnings release or material news or a material event relating to us occurs or (2) prior to the expiration of the 180-day period, we announce that we will release earnings results or become aware that material news or a material event will occur during the 16-day period beginning on the last day of the 180-day period, then the restrictions above will continue to apply until the expiration of the 18-day period beginning on the date of the issuance of the earnings release or the occurrence of the material news or material event, as the case may be, unless the representative waives, in writing, such extension.

 

Additionally, the terms of the convertible notes provide that, for 180 days after the pricing date of this offering, each holder of convertible notes will not:

 

   

directly or indirectly sell or offer to sell any shares of common stock issued upon conversion of the common stock or related securities (other than, shares offered hereby) either beneficially owned or owned of record;

 

   

enter into any swap, hedge or similar arrangement or agreement that transfers, in whole or in part, the economic risk of ownership of such shares of common stock or related securities, regardless of whether any such transaction is to be settled in securities, in cash or otherwise; or

 

   

publicly announce any intention to do any of the foregoing.

 

New York Stock Exchange Listing

 

We have applied to list our common stock on the New York Stock Exchange under the symbol “ENXP.” In order to meet the requirements for listing on that exchange, the underwriters have undertaken to sell a minimum number of shares to a minimum number of beneficial owners as required by that exchange.

 

Prior to this offering, there has been no public market for our common stock. The initial public offering price is determined by negotiations between us and the representative. Among the factors to be considered in determining the initial public offering price will be the information set forth in this prospectus; our history, present state of development and future prospects; an assessment of our management, its past and present operations and the prospects for and timing of future revenues; the history of and future prospects for our industry in general; our sales, earnings and certain other financial and operating information in recent periods; and the price-earnings ratios, price-sales ratios, market prices of securities, valuation multiples and certain financial and operating information of companies engaged in activities similar to ours.

 

An active trading market for the shares may not develop. It is also possible that after the offering the shares will not trade in the public market at or above the initial public offering price.

 

Price Stabilization, Short Positions and Penalty Bids

 

Until the distribution of the shares is completed, SEC rules may limit underwriters and selling group members from bidding for and purchasing our common stock. However, the representative may engage in transactions that stabilize the price of the common stock, such as bids or purchases to peg, fix or maintain that price.

 

In connection with the offering, the underwriters may purchase and sell our common stock in the open market. These transactions may include over-allotment and stabilizing transactions, passive market making and purchases to cover syndicate short positions created in connection with this offering. Short sales involve the sale by the underwriters of a greater number of shares than they are required to purchase in the offering. “Covered” short sales are sales made in an amount not greater than the underwriters’ option to purchase additional shares described above. The underwriters may close out any covered short position by either exercising their option to purchase additional shares or purchasing shares in the open market. In determining the source of shares to close

 

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out the covered short position, the underwriters will consider, among other things, the price of shares available for purchase in the open market as compared to the price at which they may purchase shares through the option to purchase additional shares. “Naked” short sales are sales in excess of the option to purchase additional shares. The underwriters must close out any naked short position by purchasing shares in the open market. A naked short position is more likely to be created if the underwriters are concerned that there may be downward pressure on the price of our common stock in the open market after pricing that could adversely affect investors who purchase in the offering. Stabilizing transactions consist of various bids for or purchases of shares of common stock made by the underwriters in the open market prior to the completion of the offering.

 

The underwriters also may impose a penalty bid, whereby the underwriters may reclaim selling concessions allowed to syndicate members or other broker-dealers in respect of the common stock sold in the offering for their account if the underwriters repurchase the shares in stabilizing or covering transactions.

 

These activities may stabilize, maintain or otherwise affect the market price of the common stock, which may be higher than the price that might otherwise prevail in the open market. The underwriters may conduct these transactions on the New York Stock Exchange, in the over-the-counter market or otherwise.

 

Neither we nor any of the underwriters make any representation or prediction as to the direction or magnitude of any effect that the transactions described above may have on the price of our common stock. In addition, neither we nor any of the underwriters make any representation that the representative will engage in these transactions or that these transactions, once commenced, will not be discontinued without notice.

 

Electronic Distribution

 

In connection with the offering, certain of the underwriters or securities dealers may distribute prospectuses by electronic means, such as e-mail.

 

Conflicts of Interest

 

The underwriters and their respective affiliates are full service financial institutions engaged in various activities, which may include securities trading, commercial and investment banking, financial advisory, investment management, investment research, principal investment, hedging, financing and brokerage activities. Certain of the underwriters and their respective affiliates have, from time to time, performed, and may in the future perform, various financial advisory and investment banking services for us, for which they received or will receive customary fees and expenses. Citigroup Global Markets Inc. and Credit Suisse Securities (USA) LLC acted as joint book-running managers and initial purchasers in the offering of our convertible notes and as joint book-runners and joint lead arrangers for our senior secured term loan. Additionally, an affiliate of Credit Suisse Securities (USA) LLC is the administrative agent and collateral agent and a lender under our senior secured term loan.

 

In the ordinary course of their various business activities, the underwriters and their respective affiliates may make or hold a broad array of investments and actively trade debt and equity securities (or related derivative securities) and financial instruments (including bank loans) for their own account and for the accounts of their customers, and such investment and securities activities may involve our securities and/or instruments. The underwriters and their respective affiliates may also make investment recommendations and/or publish or express independent research views in respect of such securities or instruments and may at any time hold, or recommend to clients that they acquire, long and/or short positions in such securities and instruments.

 

Notice to Prospective Investors in the European Economic Area

 

In relation to each Member State of the European Economic Area which has implemented the Prospectus Directive (each, a “Relevant Member State”), with effect from and including the date on which the Prospectus Directive is implemented in that Relevant Member State (the “Relevant Implementation Date”), no offer of shares may be made to the public in that Relevant Member State other than:

 

  A.   to any legal entity which is a qualified investor as defined in the Prospectus Directive;

 

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  B.   to fewer than 100 or, if the Relevant Member State has implemented the relevant provision of the 2010 PD Amending Directive, 150, natural or legal persons (other than qualified investors as defined in the Prospectus Directive), as permitted under the Prospectus Directive, subject to obtaining the prior consent of the representative; or

 

  C.   in any other circumstances falling within Article 3(2) of the Prospectus Directive, provided that no such offer of shares shall require us or the representative to publish a prospectus pursuant to Article 3 of the Prospectus Directive or supplement a prospectus pursuant to Article 16 of the Prospectus Directive.

 

Each person in a Relevant Member State (other than a Relevant Member State where there is a Permitted Public Offer) who initially acquires any shares or to whom any offer is made will be deemed to have represented, acknowledged and agreed that (A) it is a “qualified investor” within the meaning of the law in that Relevant Member State implementing Article 2(1)(e) of the Prospectus Directive, and (B) in the case of any shares acquired by it as a financial intermediary, as that term is used in Article 3(2) of the Prospectus Directive, the shares acquired by it in the offering have not been acquired on behalf of, nor have they been acquired with a view to their offer or resale to, persons in any Relevant Member State other than “qualified investors” as defined in the Prospectus Directive, or in circumstances in which the prior consent of the Subscribers has been given to the offer or resale. In the case of any shares being offered to a financial intermediary as that term is used in Article 3(2) of the Prospectus Directive, each such financial intermediary will be deemed to have represented, acknowledged and agreed that the shares acquired by it in the offer have not been acquired on a non-discretionary basis on behalf of, nor have they been acquired with a view to their offer or resale to, persons in circumstances which may give rise to an offer of any shares to the public other than their offer or resale in a Relevant Member State to qualified investors as so defined or in circumstances in which the prior consent of the representative has been obtained to each such proposed offer or resale.

 

We, the representative and its affiliates will rely upon the truth and accuracy of the foregoing representation, acknowledgement and agreement.

 

This prospectus has been prepared on the basis that any offer of shares in any Relevant Member State will be made pursuant to an exemption under the Prospectus Directive from the requirement to publish a prospectus for offers of shares. Accordingly any person making or intending to make an offer in that Relevant Member State of shares which are the subject of the offering contemplated in this prospectus may only do so in circumstances in which no obligation arises for us or any of the underwriters to publish a prospectus pursuant to Article 3 of the Prospectus Directive in relation to such offer. Neither we nor the underwriters have authorized, nor do they authorize, the making of any offer of shares in circumstances in which an obligation arises for us or the underwriters to publish a prospectus for such offer.

 

For the purpose of the above provisions, the expression “an offer to the public” in relation to any shares in any Relevant Member State means the communication in any form and by any means of sufficient information on the terms of the offer and the shares to be offered so as to enable an investor to decide to purchase or subscribe the shares, as the same may be varied in the Relevant Member State by any measure implementing the Prospectus Directive in the Relevant Member State and the expression “Prospectus Directive” means Directive 2003/71/EC (including the 2010 PD Amending Directive, to the extent implemented in the Relevant Member States) and includes any relevant implementing measure in the Relevant Member State and the expression “2010 PD Amending Directive” means Directive 2010/73/EU.

 

Notice to Prospective Investors in the United Kingdom

 

In addition, in the United Kingdom, this document is being distributed only to, and is directed only at, and any offer subsequently made may only be directed at persons who are “qualified investors” (as defined in the Prospectus Directive) (i) who have professional experience in matters relating to investments falling within Article 19 (5) of the Financial Services and Markets Act 2000 (Financial Promotion) Order 2005, as amended (the “Order”) and/or (ii) who are high net worth companies (or persons to whom it may otherwise be lawfully

 

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communicated) falling within Article 49(2)(a) to (d) of the Order (all such persons together being referred to as “relevant persons”). This document must not be acted on or relied on in the United Kingdom by persons who are not relevant persons. In the United Kingdom, any investment or investment activity to which this document relates is only available to, and will be engaged in with, relevant persons.

 

Notice to Prospective Investors in Switzerland

 

The shares may not be publicly offered in Switzerland and will not be listed on the SIX Swiss Exchange (“SIX”) or on any other stock exchange or regulated trading facility in Switzerland. This document has been prepared without regard to the disclosure standards for issuance prospectuses under art. 652a or art. 1156 of the Swiss Code of Obligations or the disclosure standards for listing prospectuses under art. 27 ff. of the SIX Listing

 

Rules or the listing rules of any other stock exchange or regulated trading facility in Switzerland. Neither this document nor any other offering or marketing material relating to the shares or the offering may be publicly distributed or otherwise made publicly available in Switzerland.

 

Neither this document nor any other offering or marketing material relating to the offering, us, the shares have been or will be filed with or approved by any Swiss regulatory authority. In particular, this document will not be filed with, and the offer of shares will not be supervised by, the Swiss Financial Market Supervisory Authority FINMA (“FINMA”), and the offer of shares has not been and will not be authorized under the Swiss Federal Act on Collective Investment Schemes (“CISA”). The investor protection afforded to acquirers of interests in collective investment schemes under the CISA does not extend to acquirers of shares.

 

Notice to Prospective Investors in the Dubai International Financial Centre

 

This prospectus supplement relates to an Exempt Offer in accordance with the Offered Securities Rules of the Dubai Financial Services Authority (“DFSA”). This prospectus supplement is intended for distribution only to persons of a type specified in the Offered Securities Rules of the DFSA. It must not be delivered to, or relied on by, any other person. The DFSA has no responsibility for reviewing or verifying any documents in connection with Exempt Offers. The DFSA has not approved this prospectus supplement nor taken steps to verify the information set forth herein and has no responsibility for the prospectus supplement. The shares to which this prospectus supplement relates may be illiquid and/or subject to restrictions on their resale. Prospective purchasers of the shares offered should conduct their own due diligence on the shares. If you do not understand the contents of this prospectus supplement you should consult an authorized financial advisor.

 

Notice to Prospective Investors in Hong Kong, Singapore, and Japan

 

The shares may not be offered or sold by means of any document other than (i) in circumstances which do not constitute an offer to the public within the meaning of the Companies Ordinance (Cap.32, Laws of Hong Kong), or (ii) to “professional investors” within the meaning of the Securities and Futures Ordinance (Cap.571, Laws of Hong Kong) and any rules made thereunder, or (iii) in other circumstances which do not result in the document being a “prospectus” within the meaning of the Companies Ordinance (Cap.32, Laws of Hong Kong), and no advertisement, invitation or document relating to the shares may be issued or may be in the possession of any person for the purpose of issue (in each case whether in Hong Kong or elsewhere), which is directed at, or the contents of which are likely to be accessed or read by, the public in Hong Kong (except if permitted to do so under the laws of Hong Kong) other than with respect to shares which are or are intended to be disposed of only to persons outside Hong Kong or only to “professional investors” within the meaning of the Securities and Futures Ordinance (Cap. 571, Laws of Hong Kong) and any rules made thereunder.

 

This prospectus has not been registered as a prospectus with the Monetary Authority of Singapore. Accordingly, this prospectus and any other document or material in connection with the offer or sale, or invitation for subscription or purchase, of the shares may not be circulated or distributed, nor may the shares be

 

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offered or sold, or be made the subject of an invitation for subscription or purchase, whether directly or indirectly, to persons in Singapore other than (i) to an institutional investor under Section 274 of the Securities and Futures Act, Chapter 289 of Singapore (the “SFA”), (ii) to a relevant person, or any person pursuant to Section 275(1A), and in accordance with the conditions, specified in Section 275 of the SFA or (iii) otherwise pursuant to, and in accordance with the conditions of, any other applicable provision of the SFA.

 

Where the shares are subscribed or purchased under Section 275 by a relevant person which is: (a) a corporation (which is not an accredited investor) the sole business of which is to hold investments and the entire share capital of which is owned by one or more individuals, each of whom is an accredited investor; or (b) a trust (where the trustee is not an accredited investor) whose sole purpose is to hold investments and each beneficiary is an accredited investor, shares, debentures and units of shares and debentures of that corporation or the beneficiaries’ rights and interest in that trust shall not be transferable for 6 months after that corporation or that trust has acquired the shares under Section 275 except: (1) to an institutional investor under Section 274 of the SFA or to a relevant person, or any person pursuant to Section 275(1A), and in accordance with the conditions, specified in Section 275 of the SFA; (2) where no consideration is given for the transfer; or (3) by operation of law.

 

The securities have not been and will not be registered under the Financial Instruments and Exchange Law of Japan (the Financial Instruments and Exchange Law) and each underwriter has agreed that it will not offer or sell any securities, directly or indirectly, in Japan or to, or for the benefit of, any resident of Japan (which term as used herein means any person resident in Japan, including any corporation or other entity organized under the laws of Japan), or to others for re-offering or resale, directly or indirectly, in Japan or to a resident of Japan, except pursuant to an exemption from the registration requirements of, and otherwise in compliance with, the Financial Instruments and Exchange Law and any other applicable laws, regulations and ministerial guidelines of Japan.

 

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LEGAL MATTERS

 

The validity of the shares of common stock offered by this prospectus will be passed upon for Energy & Exploration Partners, Inc. by Bracewell & Giuliani LLP, Houston, Texas. Certain legal matters in connection with this offering will be passed upon for the underwriters by Mayer Brown LLP, Houston, Texas.

 

EXPERTS

 

The consolidated financial statements of Energy & Exploration Partners, Inc. as of December 31, 2013 and December 31, 2012 and for the years ended December 31, 2013, December 31, 2012 and December 31, 2011 included in this prospectus and the related registration statement have been audited by Hein & Associates LLP, an independent registered public accounting firm, as stated in their report appearing elsewhere herein, and are included in reliance upon such report and upon the authority of such firm as experts in auditing and accounting.

 

The consolidated financial statements of TreadStone Energy Partners, LLC as of December 31, 2013 and December 31, 2012 and for the years ended December 31, 2013 and December 31, 2012 included in this prospectus and the related registration statement have been audited by LaPorte, A Professional Accounting Corporation, an independent registered public accounting firm, as stated in their report appearing elsewhere herein, and are included in reliance upon such report and upon the authority of such firm as experts in auditing and accounting.

 

The information included in this prospectus regarding our estimated quantities of proved reserves, the future net revenues from those reserves and their present value as of June 1, 2014, December 31, 2013 and December 31, 2012 and the estimated quantities of proved reserves attributable to the properties acquired in the Ft. Trinidad acquisition, the future net revenues from those reserves and their present value as of June 1, 2014 is based on reports prepared by Cawley, Gillespie & Associates, Inc., independent reserve engineers, which reports are included as exhibits to the registration statement of which this prospectus is a part. These estimates are included in this prospectus in reliance upon the authority of such firm as experts in these matters.

 

WHERE YOU CAN FIND MORE INFORMATION

 

We have filed with the SEC a registration statement on Form S-1 (including the exhibits, schedules and amendments thereto) under the Securities Act, with respect to the shares of our common stock offered hereby. This prospectus does not contain all of the information set forth in the registration statement and the exhibits and schedules thereto. For further information with respect to us and the common stock offered hereby, we refer you to the registration statement and the exhibits and schedules filed therewith. Statements contained in this prospectus as to the contents of any contract, agreement or any other document are summaries of the material terms of this contract, agreement or other document. With respect to each of these contracts, agreements or other documents filed as an exhibit to the registration statement, reference is made to the exhibits for a more complete description of the matter involved. A copy of the registration statement, and the exhibits and schedules thereto, may be inspected without charge at the public reference facilities maintained by the SEC at 100 F Street NE, Washington, D.C. 20549. Copies of these materials may be obtained, upon payment of a duplicating fee, from the Public Reference Section of the SEC at 100 F Street NE, Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the operation of the public reference facility. The SEC maintains a website that contains reports, proxy and information statements and other information regarding registrants that file electronically with the SEC. The address of the SEC’s website is http://www.sec.gov.

 

After we have completed this offering, we will file annual, quarterly and current reports, proxy statements and other information with the SEC. After completion of this offering, we expect our website to be located at http://www.enxp.com, and we expect to make our periodic reports and other information filed with or furnished to the SEC available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are electronically filed with or furnished to the SEC. Information on our website or any

 

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other website is not incorporated by reference into this prospectus and does not constitute a part of this prospectus. You may read and copy any reports, statements or other information on file at the public reference rooms. You can also request copies of these documents, for a copying fee, by writing to the SEC, or you can review these documents on the SEC’s website, as described above. In addition, we will provide electronic or paper copies of our filings free of charge upon request.

 

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INDEX TO FINANCIAL STATEMENTS

 

      Page  

Energy & Exploration Partners, Inc.

  

Unaudited Pro Forma Combined and Consolidated Financial Statements:

  

Introduction

     F-2   

Unaudited Pro Forma Combined and Consolidated Balance Sheet as of June 30, 2014

     F-4   

Unaudited Pro Forma Combined and Consolidated Statement of Operations for the six months ended June 30, 2014

     F-5   

Unaudited Pro Forma Combined and Consolidated Statement of Operations for the year ended December 31, 2013

     F-6   

Notes to Unaudited Pro Forma Combined and Consolidated Financial Statements

     F-7   

Condensed Unaudited Consolidated Financial Statements as of June 30, 2014 and for the six months ended June 30, 2014 and June 30, 2013:

  

Condensed Consolidated Balance Sheet

     F-9   

Condensed Consolidated Statements of Operations

     F-10   

Condensed Consolidated Statements of Stockholders’ Equity

     F-11   

Condensed Consolidated Statements of Cash Flows

     F-12   

Notes to the Unaudited Condensed Consolidated Financial Statements

     F-13   

Consolidated Financial Statements as of December 31, 2013, and 2012 and for the years ended December 31, 2013, 2012, and 2011:

  

Report of Independent Certified Public Accountants

     F-31   

Consolidated Balance Sheets

     F-32   

Consolidated Statements of Operations

     F-33   

Consolidated Statements of Stockholders’ Equity

     F-34   

Consolidated Statements of Cash Flows

     F-35   

Notes to the Consolidated Financial Statements

     F-36   

TreadStone Energy Partners, LLC

  

Unaudited Financial Statements as of June 30, 2014 and for the six months ended June 30, 2014 and 2013

  

Balance Sheet

     F-66   

Financial Statements as of December 31, 2013 and 2012 and for the years ended December 31, 2013, and 2012

  

Report of Independent Certified Accountants

     F-79   

Balance Sheet

     F-81   

Statement of Operations

     F-82   

Statement of Changes in Members’ Capital

     F-83   

Statement of Cash Flows

     F-84   

Notes to Financial Statements

     F-85   

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

NOTES TO UNAUDITED PRO FORMA COMBINED AND CONSOLIDATED FINANCIAL STATEMENTS

 

Introduction

 

The unaudited pro forma combined and consolidated balance sheet and statement of operations as of and for the six months ended June 30, 2014 and for the year ended December 31, 2013 give effect to the transactions described below as if they had occurred on June 30, 2014 in the case of the unaudited pro forma combined and consolidated balance sheet and January 1, 2013 in the case of the unaudited pro forma combined and consolidated statements of operations.

 

The unaudited pro forma consolidated financial statements reflect the following significant assumptions and transactions:

 

   

the acquisition of oil and gas leasehold and producing oil and natural gas wells (the “Ft. Trinidad acquisition”) from TreadStone Energy Partners, LLC (“TreadStone”) for an initial cash purchase price of $719.1 million, net of negative post-closing adjustments of $25.8 million recognized as of August 31, 2014, and the assumption of certain current assets and liabilities;

 

   

the issuance of a $775.0 million senior secured term loan credit facility due 2019;

 

   

the issuance of $375.0 million principal amount of 8% convertible subordinated notes due in 2019 (the “Notes”), including the derivative embedded features;

 

   

the conversion of the Notes into shares of the Company’s common stock upon completion of this offering;

 

   

the issuance of an $18.0 million subordinated unsecured note to a subsidiary of Chesapeake Energy Corporation;

 

   

the extinguishment of the Company’s outstanding Guggenheim credit facility and senior unsecured notes, including a prepayment penalty; and

 

   

the automatic conversion of the outstanding warrants into                      shares of the Company’s common stock upon completion of this offering.

 

The Ft. Trinidad acquisition purchase price is subject to additional post-closing purchase price adjustments.

 

The unaudited pro forma combined and consolidated financial statements include the historical consolidated balance sheets and statements of operations of Energy & Exploration Partners, Inc (“ENXP” or the “Company”) and TreadStone giving effect to the transactions described above. Certain historical balance sheet and statement of operations amounts of TreadStone have been reclassified to conform to the financial statement presentation of ENXP. Nonrecurring transactions of $76.7 million of loss on the extinguishment of debt related to the retirement of the Company’s outstanding senior unsecured notes, including a prepayment penalty of $52.6 million, and $         million of loss on extinguishment of debt related to the conversion of the outstanding Notes into shares of the Company’s common stock, have been excluded from the unaudited pro forma combined and consolidated statement of operations.

 

The summary pro forma combined and consolidated statement of operations for the year ended December 31, 2013 does not include adjustments for historical revenues or operating expenses associated with the properties acquired in the Chesapeake acquisition described in Note 4 “—Significant Purchases and Sales of Assets” of the Notes to the Company’s consolidated financial statements for the year ended December 31, 2013, as the amounts were not material. Actual amounts recorded as of the completion of the Ft. Trinidad acquisition may differ materially from the information presented in these unaudited pro forma adjustments. In addition, the purchase price is subject to customary adjustments following completion of the acquisition, including but not

 

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limited to adjustments for revenues, expenses and capital expenditures from the effective date through the closing date all of which are not reflected in the unaudited pro forma financial statements.

 

The unaudited pro forma combined and consolidated financial statements are presented for illustrative purposes only and are not necessarily indicative of the consolidated financial position or consolidated results of operations of the Company that would have been reported had the transactions occurred on the dates indicated, nor do they represent a forecast of the consolidated financial position or consolidated results of operations of the Company at any future date.

 

The unaudited pro forma combined and consolidated financial statements, including the notes thereto, should be read in conjunction with (a) the historical consolidated financial statements, including the notes thereto, and other information of the Company as of and for the six months ended June 30, 2014 and for the year ended December 31, 2013 included elsewhere in this prospectus, and (b) the historical financial statements of TreadStone as of and for the six months ended June 30, 2014 and for the year ended December 31, 2013 included elsewhere in this prospectus.

 

See the accompanying notes to these unaudited pro forma combined and consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC

 

UNAUDITED PRO FORMA COMBINED AND CONSOLIDATED

BALANCE SHEET

AS OF JUNE 30, 2014

(In thousands)

 

    ENXP
Historical
    TreadStone
Historical
    Acquisition
Adjustment(a)
    Debt Issuance
Adjustment(b)
    Debt Conversion
at IPO(c)
    As
Adjusted
 
ASSETS            

Current assets:

           

Cash and cash equivalents

    2,706        12,341        (705,601     822,074        —          131,520   

Accounts receivable-oil and natural gas sales

    4,784        27,010        (27,010     —          —          4,784   

Accounts receivable-other

    154        920        (469     —          —          605   

Deferred tax assets

    259        —          —          —          —          259   

Derivative asset

    —          6        (6     —          —          —     

Prepaid expenses

    792        101        (101     —          —          792   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total current assets

    8,695        40,378        (733,187     822,074        —          137,960   

Property, plant, and equipment:

           

Unproved oil and natural gas properties

    74,260        18,101        (18,101     —          —          74,260   

Proved oil and natural gas properties

    234,254        192,279        509,789        —          —          936,322   

Other property and equipment

    1,136        73        (73     —          —          1,136   

Less: Accumulated depreciation, depletion, and amortization

    (29,147     (38,888     38,888        —          —          (29,147
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Net property, plant, and equipment

    280,503        171,565        530,503        —          —          982,571   

Long-term assets:

           

Loan origination fees,

    3,762        —          —          34,963        (22,367     16,358   

Long-term deposits

    196        —          —          —          —          196   

Other long-term assets

    3,317        —          —          —          —          3,317   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total long-term assets .

    7,275        —          —          34,963        (22.367     19,871   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

TOTAL ASSETS

    296,473        211,943        (202,684     857,037        (22,367     1,140,402   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 
LIABILITIES AND STOCKHOLDERS’ EQUITY            

Current liabilities:

           

Accounts payable and other accrued liabilities

    35,231        33,657        (27,029     —          —          41,859   

Deposit for investments

    22        —          —          —          —          22   

Deposit for investments - related party

    22        —          —          —          —          22   

Derivative liability

    1,430        8,166        (8,166     —          —          1,430   

Asset retirement obligation

    976        —          —          —          —          976   

Current income tax liability

    958        —          —          —          —          958   

Current portion of long-term debt

    15        —          —          7,750        —          7,765   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total current liabilities

    38,654        41,823        (35,195     7,750        —          53,032   

Long-term liabilities:

           

Asset retirement obligation

    409        4,454        (1,823     —          —          3,040   

Deferred tax liability

    259        —          —          —          —          259   

Derivative liability

    433        1,559        (1,559     74,691        (74,691     433   

Notes payable

    224,985        19,000        (19,000     851,250        (300,309     775,926   

Other current liabilities

    45        —          —          —          —          45   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total long-term liabilities

    226,131        25,013        (22,382     925,941        (375,000     779,703   

Commitments and contingencies

           

Stockholders’ equity:

           

Preferred stock

    —          —          —          —          —          —     

Common stock

    5        —          —          —         

Additional paid-in capital

    47,334        —          —          —         

Accumulated deficit

    (15,651     —          —          (76,654    

Members’ capital

    —          145,107        (145,107     —          —          —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total stockholders’ equity

    31,688        145,107        (145,107     (76,654    
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY

    296,473        211,943        (202,684     857,037       
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

See the accompanying notes to these unaudited pro forma combined and consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

UNAUDITED PRO FORMA COMBINED AND CONSOLIDATED

STATEMENT OF OPERATIONS

 

SIX MONTHS ENDED JUNE 30, 2014

(In thousands, except share and per share amounts)

 

    ENXP
Historical
    Treadstone
Historical
    Acquisition
Adjustments
          Debt
Issuance
Adjustments
          Adjusted
Balance
       

Revenues:

               

Oil and natural gas sales

    21,248        98,470        (829     (d     —            118,889     

Realized losses on commodity hedging instruments

    —          (4,046     4,046        (e     —            —       

Unrealized losses on commodity hedging instruments

    —          (6,274     6,274        (e     —            —       
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Total revenue

    21,248        88,150        9,491          —            118,889     

Operating expenses:

               

Lease operating expense

    4,395        9,675        (377     (d     —            13,693     

Production taxes

    1,054        4,749        (31     (d     —            5,772     

General and administrative expense

    8,823        1,900        (191     (e     —            10,532     

Depreciation, depletion and
amortization

    9,505        17,417        7,883        (f     —            34,805     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Total operating expenses

    23,777        33,741        7,284          —            64,802     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Income (Loss) from operations:

    (2,529     54,409        2,207          —            54,087     

Other income (expense):

               

Interest and other income

    4        —          —            —            4     

Interest expense

    (13,174     (317     317        (g     (14,909     (h     (28,083  

Loss on derivatives

    (2,174     —          (10,320     (e     —            (12,494  

Gain on sales of assets

    14,249        —          —            —            14,249     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Total other income (expense)

    (1,095     (317     (10,003       (14,909       (26,324  
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Income (loss) before income tax benefit

    (3,624     54,092        (7,796       (14,909       27,763     

Income tax benefit

    342        —          2,779        (i     5,315        (i     8,436     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Net income (loss)

    (3,282     54,092        (5,017       (9,594       36,199     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Income (loss) per share of common stock

               

Basic

  $ (6.43             $                 (c

Diluted

  $ (6.43             $                 (c

Weighted—average common shares outstanding

               

Basic

    510,530                    (c

Diluted

    510,530                    (c

 

See the accompanying notes to these unaudited pro forma combined and consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

UNAUDITED PRO FORMA COMBINED AND CONSOLIDATED

STATEMENT OF OPERATIONS

 

YEAR ENDED DECEMBER 31, 2013

(In thousands, except share and per share amounts)

 

    ENXP
Historical
    Treadstone
Historical
    Acquisition
Adjustments
          Debt
Issuance
Adjustments
          Adjusted
Balance
       

Revenues:

               

Oil and natural gas sales

    16,437        86,392        (2,407     (d     —            100,422     

Realized losses on commodity hedging instruments

    —          (2,543     2,543        (e     —            —       

Unrealized losses on commodity hedging instruments

    —          (3,444     3,444        (e     —            —       
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Total revenue

    16,437        80,405        3,580          —            100,422     

Operating expenses:

               

Lease operating expense

    3,215        8,317        (796     (d     —            10,736     

Production taxes

    866        4,126        (99     (d     —            4,893     

Full—cost ceiling impairment

    8,447        —          —            —            8,447     

General and administrative expense

    16,888        3,809        (1,066     (e     —            19,631     

Depreciation, depletion and amortization

    6,917        16,229        6,057        (f     —            29,203     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Total operating expenses

    36,333        32,481        4,096          —            72,910     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Income (Loss) from operations:

    (19,896     47,924        (516       —            27,512     

Other income (expense):

               

Interest and other income

    53        —          —            —            53     

Loss on early extinguishment of debt

    (3,677     —          —            —            (3,677  

Interest expense

    (17,211     (597     597        (g     (45,738     (h     (62,949  

Loss on derivatives

    (662     —          (5,987     (e     —            (6,649  

Gain on sales of assets

    14,275        —          —            —            14,275     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Total other income (expense)

    (7,222     (597     (5,390       (45,738       (58,947  
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Income (loss) before income tax expense

    (27,118     47,327        (5,906       (45,738       (31,435  

Income tax benefit

    5,351        —          2,105        (i     16,306        (i     23,762     
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Net income (loss)

    (21,767     47,327        (3,801       (29,432       (7,673  
 

 

 

   

 

 

   

 

 

     

 

 

     

 

 

   

Loss per share of common stock

               

Basic and diluted

  $ (43.12             $                     (c

Weighted—average common shares outstanding

               

Basic and diluted

    504,796                    (c

 

See the accompanying notes to these unaudited pro forma combined and consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

UNAUDITED PRO FORMA COMBINED AND CONSOLIDATED FINANCIAL STATEMENTS

 

Notes to Unaudited Pro Forma Combined and Consolidated Financial Statements

 

a.   Adjustments to reflect the estimated fair value of assets acquired and liabilities assumed in the Ft. Trinidad acquisition as if consummated on June 30, 2014. Adjustments include the $693.3 million cash purchase price, net of certain post-closing adjustments, $0.5 million in joint interest billing receivables, the assumption of $6.6 million in current liabilities and $2.6 million in asset retirement obligations, the elimination of TreadStone’s historical balance sheet amounts and the recognition of the proved oil and natural properties at fair value of $702.1 million. Fair value was calculated using an internal reserve study and is subject to additional post-closing purchase price adjustments.

 

b.   Adjustments to record the $375.0 million principal amount of 8% Notes due 2019 initially bearing interest at a rate of 8.0% per annum, net of $22.4 million debt origination costs and $74.7 million fair value of an embedded derivative. The Notes contain a conversion feature allowing holders to convert all or part of the Notes into shares of the Company’s common stock upon the closing of a qualified public offering. The Notes also contain a put option feature allowing holders to require the Company to repurchase for cash all or a part of the outstanding Notes if the Company undergoes a change of control. Both of the embedded features meet the definition of a derivative under ASC 815 and require bifurcation and are accounted for as a separate combined embedded derivative. Therefore, initially the embedded derivative will be recorded on the balance sheet at its estimated fair value of $74.7 million and will create a discount on the Notes.

 

Adjustments to record $775.0 million principal amount of borrowings under a new senior secured term loan credit facility due 2019, at an interest rate of 7.75%, net of 1.50% original issue discount and $16.4 million debt origination costs.

 

Adjustments to record the extinguishment of the Company’s outstanding senior unsecured notes totalling 204.7 million, net of discounts and the estimated prepayment penalty of $52.6 million.

 

c.   Adjustments to reflect the conversion of the outstanding Notes into              shares of the Company’s common stock upon completion of this offering, assuming an initial public offering price of $         per share and that conversion rights are exercised with respect to all of the outstanding Notes. The Company expects that conversion rights will be exercised with respect to all of the Notes because it has the option to redeem any Notes not converted at a redemption price equal to 100% of the principal amount of the Notes redeemed, plus accrued interest.

 

Adjustments to record the loss on extinguishment of Notes and derivative liability surrendered in exchange for common stock. The fair value of the common stock exchanged for the Notes and derivative liability exceeded the net carrying amount of the debt and derivative liability resulting in a $         million loss on conversion to common stock.

 

Adjustments to record the automatic conversion of the Company’s warrants into                  shares of common stock upon completion of this offering.

 

d.   Eliminate revenues and expenses that were included in the historical results of operations for TreadStone related to properties not acquired by the Company.

 

e.   Reclassification to conform to the Company’s presentation.

 

f.   Adjustment to depreciation, depletion and amortization (“DD&A”) to recognize depletion on acquired assets and to adjust the Company’s historical DD&A to reflect the revised combined depletion rate under the full cost method of accounting.

 

g.   Eliminate interest expense included in the historical results of operations for TreadStone related to debt not assumed by the Company.

 

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h.  

Adjustment to interest expense to reflect the new financing, including borrowings under the senior secured term loan credit facility, amortization of discount and debt issuance costs using the effective interest method, and the extinguishment of the Company’s previously outstanding Guggenheim credit facility and senior unsecured notes. Since current LIBOR rates are below the 1% floor included in the senior secured term loan credit facility a  1/8th. percent change in market rates will not impact the Company’s net income.

 

i.   Adjustment to recognize income tax effect of the pro forma adjustments based on the Company’s 35.6% statutory rate.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except par value and share amounts)

 

     December 31,
2013
    June 30,
2014
 
           (unaudited)  
ASSETS     

Current assets:

    

Cash and cash equivalents

   $ 3,569      $ 2,706   

Accounts receivable-oil and natural gas sales

     4,816        4,784   

Accounts receivable-other

     —          154   

Deferred tax assets

     271        259   

Prepaid expenses

     617        792   
  

 

 

   

 

 

 

Total current assets

     9,273        8,695   

Property, plant, and equipment:

    

Unproved oil and natural gas properties

     89,086        74,260   

Proved oil and natural gas properties

     158,955        234,254   

Other property and equipment

     979        1,136   

Less: Accumulated depreciation, depletion and amortization

     (19,763     (29,147
  

 

 

   

 

 

 

Net property, plant, and equipment

     229,257        280,503   

Long-term assets:

    

Loan origination fees, net of amortization of $179 and $393, respectively

     1,782        3,762   

Long-term deposits

     87        196   

Other long-term assets

     3,174        3,317   
  

 

 

   

 

 

 

Total long-term assets

     5,043        7,275   
  

 

 

   

 

 

 

TOTAL ASSETS

   $ 243,573      $ 296,473   
  

 

 

   

 

 

 
LIABILITIES AND STOCKHOLDERS’ EQUITY     

Current liabilities:

    

Accounts payable

   $ 29,319      $ 13,507   

Accrued and other liabilities

     12,133        21,724   

Accrued interest

     58       —     

Deposit for investments

     22       22   

Deposit for investment-related party

     22       22   

Derivative liability

     543       1,430   

Asset retirement obligation

     655       976   

Current income tax liability

     1,298        958   

Other current liabilities

     —          15   
  

 

 

   

 

 

 

Total current liabilities

     44,050        38,654   
  

 

 

   

 

 

 

Long-term liabilities:

    

Asset retirement obligation

     637        409   

Deferred tax liability

     271        259   

Derivative liability

     14        433   

Notes payable, net of discount of $16,006 and $20,316, respectively

     168,336        224,985   

Other non-current liabilities

     —          45   
  

 

 

   

 

 

 

Total long-term liabilities

     169,258        226,131   
  

 

 

   

 

 

 

Commitments and contingencies (Note 12)

    

Stockholders’ equity:

    

Preferred stock, $0.01 par value; 750,000 shares authorized; no shares issued or outstanding

     —          —     

Common stock, $0.01 par value; 1,200,000 shares authorized, 510,530 shares issued and outstanding, at December 31, 2013 and June 30, 2014

     5        5   

Additional paid-in capital

     42,629        47,334   

Accumulated deficit

     (12,369     (15,651
  

 

 

   

 

 

 

Total stockholders’ equity

     30,265        31,688   
  

 

 

   

 

 

 

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY

   $ 243,573      $ 296,473   
  

 

 

   

 

 

 

 

See accompanying notes to these condensed consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except share and per share amounts)

(Unaudited)

 

     Six Months Ended
June 30
 
   2013     2014  

Revenues:

    

Oil and natural gas sales

   $ 1,942      $ 21,248   

Operating expenses:

    

Lease operating expense

     321        4,395   

Production taxes

     104        1,054   

Full-cost ceiling impairment

     8,447        —     

General and administrative expense

     8,735        8,823   

Depreciation, depletion and amortization

     1,188        9,505   
  

 

 

   

 

 

 

Total operating expenses

     18,795        23,777   
  

 

 

   

 

 

 

Loss from operations

     (16,853     (2,529

Other income (expense):

    

Interest and other income.

     33        4   

Loss on early extinguishment of debt

     (3,677     —     

Interest expense

     (7,132     (13,174

Loss on derivatives

     —          (2,174

Gain (loss) on sales of assets

     14,275        14,249   
  

 

 

   

 

 

 

Total other income (expense), net

     3,499        (1,095
  

 

 

   

 

 

 

Loss before income tax benefit

     (13,354     (3,624

Income tax benefit

     3,922        342   
  

 

 

   

 

 

 

Net loss

   $ (9,432   $ (3,282
  

 

 

   

 

 

 

Basic and dilutive:

    

Net loss attributable to common stock—Basic and diluted

   $ (18.82   $ (6.43

Weighted average shares of common stock outstanding—Basic and diluted

     501,068        510,530   

 

See accompanying notes to these condensed consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

 

(In thousands, except share amounts)

(Unaudited)

 

     Common
stock shares
    Common
stock,
par value
     Preferred
stock
     Additional
paid in
capital
     Retained
earnings
(deficit)
    Total
equity
 

TOTAL STOCKHOLDERS’ EQUITY

               

December 31, 2012

     500,000      $ 5       $ —         $ 19,162       $ 9,397      $ 28,564   

Equity owner contribution

     (2,500     —           —           —           —          —     

Share-based compensation

     13,030        —           —           9,704         —          9,704   

Warrant issuance

     —          —           —           13,763         —          13,763   

Net loss

     —          —           —           —           (21,767     (21,767
  

 

 

   

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

TOTAL STOCKHOLDERS’ EQUITY

               

December 31, 2013

     510,530      $ 5       $ —         $ 42,629       $ (12,369   $ 30,265   

Share-based compensation

     —          —           —           1,059         —          1,059   

Warrant issuance

     —          —           —           3,646         —          3,646   

Net income

     —          —           —           —           (3,282     (3,282
  

 

 

   

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

TOTAL STOCKHOLDERS’ EQUITY

               

June 30, 2014

     510,530      $ 5       $ —         $ 47,334       $ (15,651   $ 31,688   
  

 

 

   

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

 

See accompanying notes to these condensed consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

 

     Six Months Ended
June 30
 
     2013     2014  

Cash flows from operating activities:

    

Net loss

   $ (9,432   $ (3,282

Adjustments to reconcile net income to net cash used in by operating activities:

    

Gain on sales of oil and natural gas assets

     (14,275     (14,249

Full-cost ceiling impairment

     8,447        —     

Depreciation, depletion and amortization

     1,188        9,505   

Non-cash interest, discount and amortization of debt costs

     2,441        3,451   

Share based compensation expense

     5,796        713   

Change in fair value of commodity derivatives

     —         1,306   

Deferred income tax benefit

     (612     —     

Adjustments to working capital to arrive at net cash used in operating activities:

    

Accounts receivable

     520        (122

Prepaid expenses and other assets

     (131     (286

Accounts payable- related party

     (2     —     

Current income tax liability

     (4,019     (340

Accounts payable, accrued and other liabilities

     9,483        (10,443
  

 

 

   

 

 

 

Net cash used in operating activities

     (596     (13,747
  

 

 

   

 

 

 

Cash flows from investing activities:

    

Oil and natural gas capital expenditures

     (90,298     (61,594

Proceeds from the sale of oil and gas properties, net of transaction costs

     19,665        19,883   

Acquisition of furniture, fixtures, and equipment

     (43     (201

Purchase of security deposits

     (11     —     
  

 

 

   

 

 

 

Net cash used in investing activities

     (70,687     (41,912
  

 

 

   

 

 

 

Cash flows from financing activities:

    

Proceeds from notes payable, net of debt service deposits funded and discounts

     135,991        57,000   

Payments on notes payable, net of debt service deposits returned

     (17,284     —     

Payments of deferred offering costs

     (220     (11

Payments of loan origination costs

     (2,392     (2,193
  

 

 

   

 

 

 

Net cash provided by financing activities

     116,095        54,796   
  

 

 

   

 

 

 

Net change in cash and cash equivalents

     44,812        (863

Cash and cash equivalents at beginning of period

     10,228        3,569   
  

 

 

   

 

 

 

Cash and Cash equivalents at end of period

   $ 55,040      $ 2,706   
  

 

 

   

 

 

 

Supplemental disclosure of cash flow information:

    

Cash paid for interest

   $ 8,552      $ 15,163   
  

 

 

   

 

 

 

Cash paid for taxes

   $ 709      $ —     
  

 

 

   

 

 

 

Non-cash investing and financing activities:

    

Payment-in-kind interest

   $ 414      $ 959   
  

 

 

   

 

 

 

Original issue discount on notes payable

   $ 4,200      $ 3,000   
  

 

 

   

 

 

 

Warrants issued in conjunction with notes payable

   $ 13,763      $ 3,646   
  

 

 

   

 

 

 

Asset retirement obligations

   $ 226      $ 8   
  

 

 

   

 

 

 

 

See accompanying notes to these condensed consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

 

1. Organization

 

Energy & Exploration Partners, Inc. (together with our consolidated subsidiaries, “ENXP,” “the Company,” “we,” “our,” “us” or similar terms) was incorporated pursuant to the laws of the State of Delaware in July 2012. ENXP is an independent exploration and production company focused on the acquisition, exploration, development and exploitation of unconventional oil and natural gas resources. The Company has undeveloped leasehold acres in three basins: the East Texas Basin where the Company is pursuing opportunities in the Lower Cretaceous formations of the Buda, Georgetown, Edwards and Glen Rose (the Buda-Rose play), the Woodbine sandstone, and the Eagle Ford shale, collectively referred to as the East Texas stacked play; the Permian Basin in West Texas; and the Denver-Julesburg Basin in Wyoming, referred to as the DJ Basin. The Company focuses on liquids-rich resource plays and believes that a substantial portion of its acreage is oil-prone. The Company plans to continue to pursue additional leasehold acquisitions in its East Texas stacked play core area and pursue other emerging opportunities.

 

2. Financial Statement Presentation

 

Basis of Presentation

 

ENXP’s consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (“U.S. GAAP”). All significant intercompany transactions and account balances have been eliminated. As a company with less than $1.0 billion in revenue during its last fiscal year, the Company qualifies as an emerging growth company as defined in the recently enacted Jumpstart Our Business Startups Act of 2012, or the JOBS Act. An emerging growth company may take advantage of exemptions from various reporting requirements that are applicable to public companies that are not an “emerging growth company.”

 

Interim Financial Statements

 

The condensed balance sheet as of December 31, 2013, which had been derived from audited financial statements and the unaudited interim condensed financial statements as of June 30, 2014 and for the six month periods ended June 30, 2014 and 2013, included herein, are unaudited but reflect, in the opinion of management, all adjustments necessary to fairly state the results for such periods. The results of operations for the six months ended June 30, 2014 are not necessarily indicative of the results of operations expected for the year ended December 31, 2014.

 

These interim consolidated financial statements should be read in conjunction with the audited consolidated financial statements of Energy & Exploration Partners, Inc. for the years ended December 31, 2013, 2012 and 2011 and the notes thereto.

 

Reclassifications

 

Certain reclassifications have been made to the prior period’s financial statements to conform to the current year presentation. These reclassifications had no effect on previously reported results of operations, cash flows or retained earnings. These reclassifications include $104,000 related to production taxes formerly presented as lease operating expense and currently presented as production tax expense on the unaudited condensed consolidated statement of operations for the six months ended June 30, 2013, and $903,000 related to income tax penalties and interest formerly presented as general and administrative expense and currently presented as income tax expense on the unaudited condensed consolidated statement of operations for six months ended June 30, 2013.

 

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Recent Accounting Pronouncements

 

In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). ASU 2014-09 amends the guidance for revenue recognition to replace numerous, industry-specific requirements. The core principle of the amendment is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The amendment implements a five-step process for customer contract revenue recognition that focuses on transfer of control, as opposed to transfer of risk and rewards. The amendment also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers. The amendments are effective for reporting periods beginning after December 15, 2016, and early adoption is prohibited. Entities can transition to the standard either retrospectively to each period presented or as a cumulative-effect adjustment as of the date of adoption. The Company has not determined the impact the adoption of ASU 2014-09 will have on its consolidated financial statements or the method it will utilize upon adoption during the first quarter of 2017.

 

3. Oil and natural gas properties and equipment

 

The following table presents a summary of the Company’s oil and natural gas properties and related accumulated depletion as of December 31, 2013 and June 30, 2014 (in thousands):

 

     December 31,     June 30,  
   2013     2014  

Oil and natural gas properties

    

Unproved properties

   $ 89,086      $ 74,260   

Proved properties

     158,955        234,254   
  

 

 

   

 

 

 

Total oil and natural gas properties

     248,041        308,514   

Accumulated depletion(1)

     (19,368     (28,678
  

 

 

   

 

 

 

Net oil and natural gas properties

   $ 228,673      $ 279,836   
  

 

 

   

 

 

 

 

(1)   Accumulated depletion and impairment as of December 31, 2013 and June 30, 2014 include full cost ceiling impairment expense of approximately $12.4 million.

 

Investments in unevaluated oil and natural gas properties and exploration and development projects for which depletion expense is not currently recognized, and for which exploration or development activities are in progress, qualify for interest capitalization. The capitalized interest is determined by multiplying the Company’s weighted-average borrowing cost on debt by the average amount of qualifying costs incurred that are excluded from the full cost pool; however, the amount of capitalized interest cannot exceed the amount of gross interest expense incurred in any given period. The capitalized interest amounts are recorded as additions to unevaluated oil and natural gas properties on the consolidated balance sheets. As the costs excluded are transferred to the full cost pool, the associated capitalized interest is also transferred to the full cost pool. For the year ended December 31, 2013 and the six months ended June 30, 2014 the Company capitalized interest costs of $3.8 million and $5.4 million, respectively.

 

The Company capitalizes certain general and administrative costs, including share based compensation costs, related to individuals directly involved in the Company’s acquisition, exploration and development activities based on the percentage of their time devoted to such activities. These costs include employee compensation and related benefits. For the year ended December 31, 2013 and the six months ended June 30, 2014, the Company capitalized general and administrative costs of $3.6 million and $1.1 million, respectively.

 

Impairment and Abandonment of Unevaluated Properties

 

ENXP’s unproved and unevaluated properties are assessed at a minimum on an annual basis on an individual prospect level for possible impairment based upon changes in operating or economic conditions.

 

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Unproved and unevaluated properties are nonproducing and do not have estimable cash flow streams. Therefore, the Company estimates the fair value of these properties by obtaining, when available, information about recent market transactions in the vicinity of the prospects and adjusts the market data as needed to give consideration to the proximity of the prospects to known fields and reservoirs, the extent of geological and geophysical data on the prospects, the assignment of proved reserves, intent to drill, remaining lease terms, recent drilling results in the vicinity of the prospects, and other risk-related factors such as drilling and completion costs, estimated product prices and other economic factors. Based on these assessments, the Company includes the cost of such properties whose carrying value exceeds its estimated value with other evaluated properties to be amortized and subject to the full-cost ceiling impairment of oil and natural gas properties. The Company categorizes the measurement of fair value of unproved properties as level 3 non-recurring measurements.

 

During the year ended December 31, 2013 and the six months ended June 30, 2014, the Company transferred $18.5 million and $14.5 million, respectively, of unevaluated property costs to the full cost pool related to impaired value, primarily due to a decline in fair value of certain leases related to the remaining lease terms. No impairment was recognized for the six months ended June 30, 2013.

 

Full-Cost Ceiling Impairment of Oil and Natural Gas Properties

 

Under the full cost method of accounting for oil and natural gas properties, net capitalized costs of oil and natural gas properties are limited to the lower of unamortized costs less related deferred income taxes or the cost ceiling, with any excess above the cost center ceiling charged to the statement of operations as a full-cost ceiling impairment. Properties included in the total net capitalized costs include, but are not limited to, proved properties, unproved evaluated properties and unevaluated properties deemed to have been impaired.

 

ENXP’s net capitalized costs at June 30, 2014 did not exceed the ceiling amount. As a result, the Company did not record an impairment related to the full cost ceiling test at June 30, 2014. However, ENXP’s net capitalized costs at March 31, 2013 exceeded the ceiling amount and the Company recorded a full cost ceiling test impairment of $8.4 million for the six months ended June 30, 2013.

 

4. Significant Sales of Assets

 

Net gains on sales of assets for the six months ended June 30, 2013 and 2014 are as follows (in thousands):

 

     Six months ended June 30,  
         2013              2014      

Gain on sale of assets . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

   $ 14,275       $ 14,249   

 

Pursuant to the Company’s agreement with Halcón Resources, Inc. (“Halcón”), working interests conveyed to Halcón were subject to a contingent payment of $1,000 per net acre conveyed, subject to the commercial production of one or two wells drilled and completed within the area of mutual interest created pursuant to the agreement. During the six months ended June 30, 2013, one of the wells became commercial and Halcón elected to pay one-half of the contingent payment, or $14.6 million to the Company. The Company follows the full cost method of accounting for its oil and gas properties. Generally, under this method, sales are accounted for as adjustments to capital costs, with no gains or losses realized unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves to such cost center. As this contingent payment is part of a previous sale which significantly altered the relationship between the basis in the Company’s properties and the Company’s de minimis proved reserves at the time of sale, the proceeds of $14.6 million net of $0.4 million in fees associated with the receipt of the proceeds is shown as a gain on the statement of operations during the six months ended June 30, 2013. Additionally, on March 31, 2014, Halcón elected to pay the remaining $14.6 million of the contingent payment by May 15, 2014. The Company received the contingent payment in May 2014 and has shown the payment received of $14.6 million net of $0.4 million in costs associated with this payment as a gain on the statement of operations at June 30, 2014.

 

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During June 2014, the Company completed the disposition of certain oil and gas leaseholds in Houston and Robertson Counties, Texas, to several oil and gas companies for sales proceeds of approximately $5.4 million in cash. The sales proceeds were recorded as a reduction to the capital costs in the full cost pool in accordance with the company’s methodology in accounting for its oil and gas properties as described above.

 

5. Asset Retirement Obligations

 

The Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred and if a reasonable estimate of fair value can be made. The asset retirement obligation is capitalized as part of the carrying amount of the long-lived asset. The Company determines its asset retirement obligations on its oil and natural gas properties by calculating the present value of estimated cash flows related to the estimated liability. The fair value of the liability is measured on a non-recurring basis using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging, abandonment and remediation costs, inflation rate and well life. The inputs are calculated based on historical data as well as current estimated costs. See Note 9—Fair Value Measures for additional discussion.

 

The following table summarizes the changes in the Company’s ARO for the year ended December 31, 2013 and the six months ended June 30, 2014 (in thousands).

 

     December 31,
2013
    June 30,
2014
 

Liability for asset retirement obligation, beginning of period

   $ 16      $ 1,292   

Obligations for wells acquired and wells drilled

     338        8   

Change in estimate

     840        —     

Accretion expense

     98        85   
  

 

 

   

 

 

 

Liability for asset retirement obligation, end of period

     1,292        1,385   

Less: current asset retirement obligation

     (655     (976
  

 

 

   

 

 

 

Long-term asset retirement obligation

   $ 637      $ 409   
  

 

 

   

 

 

 

 

6. Notes Payable

 

The following table summarizes the Company’s debt as of December 31, 2013 and June 30, 2014 (in thousands):

 

     December 31,
2013
     June 30,
2014(6)
 

Senior Unsecured Note—Tranche A(1)

   $ 124,731       $ 126,528   

Senior Unsecured Note—Tranche B(2)

     24,263         24,337   

Senior Unsecured Note—Tranche C(3)

     —           13,902   

Senior Unsecured Note—Tranche D(4)

     —           39,916   

Subordinated Unsecured Note—Chesapeake(5)

     19,342         20,302   
  

 

 

    

 

 

 

Total debt

   $ 168,336       $ 224,985   
  

 

 

    

 

 

 

 

(1)   Amount is net of unamortized discount of $15.3 million and $13.5 million at December 31, 2013 and June 30, 2014 respectively. See “Senior Unsecured Notes” below for more details.
(2)   Amount is net of unamortized discount of $0.8 million and $0.7 million at December 31, 2013 and June 30, 2014 respectively. See “Senior Unsecured Notes” below for more details.
(3)   Amount is net of unamortized discount of $1.1 million at June 30, 2014. See “Senior Unsecured Notes” below for more details.
(4)   Amount is net of unamortized discount of $5.1 million at June 30, 2014. See “Senior Unsecured Notes” below for more details.

 

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(5)   Amount includes paid in kind interest of $1.3 million and $2.3 million at December 31, 2013 and June 30, 2014 respectively. See “Subordinated Unsecured Note” below for more details.
(6)   See Note 12 Commitments and Contingencies for a five year maturity schedule.

 

Senior Unsecured Note

 

Tranche A Notes

 

On April 8, 2013, ENXP issued $140.0 million of senior unsecured notes (“the Tranche A notes”) with an original issue discount of 3%, or $4.2 million, to affiliates of Highbridge Principal Strategies, LLC, (“Highbridge”), and affiliates of Apollo Investment Corporation, (“Apollo”). These notes mature on April 8, 2018.

 

Tranche B Notes

 

On December 12, 2013, ENXP entered into the first supplement to its senior unsecured notes agreement and issued $25.0 million of senior unsecured notes (“the Tranche B notes”) with an original issue discount of 3%, or $0.8 million, to Highbridge and Apollo. These notes mature on December 12, 2018.

 

Tranche C Notes

 

On January 31, 2014, ENXP entered into the second supplement to its senior unsecured notes agreement and issued $15.0 million of senior unsecured notes (the “Tranche C notes”) with an original issue discount of 8%, or $1.2 million, to Highbridge and Apollo. These notes mature on December 12, 2018.

 

From January 31, 2014 through January 30, 2018, the Tranche C notes bear interest at a rate equal to the greater of (i) 15% per year and (ii) the annual rate payable on the Term Loan once funded plus 2%. If the Company does not refinance the Tranche B notes by January 30, 2018, the interest rate from January 31, 2018 until maturity will be the greater of (i) 20% per year and (ii) the annual rate payable on the Term Loan plus 2% interest is due quarterly.

 

Tranche D Notes

 

On March 27, 2014, ENXP entered into the third supplement to its senior unsecured notes agreement and issued $60.0 million of senior unsecured notes (the “Tranche D notes”) to Highbridge and Apollo. The Company issued an aggregate of $45.0 million of senior unsecured notes with an original issue discount of 4%, or $1.8 million, in the initial funding on March 27, 2014 and has an option, subject to achievement of certain conditions precedent, to issue additional notes in the aggregate amount of $15.0 million in future periods, but no later than September 30, 2014. The initial March 2014 funding of Tranche D notes will mature on March 27, 2019 and will bear interest from the date of funding until March 26, 2018 at a rate of 15% per year. Thereafter, the interest rate will increase to 20% until maturity of the initial Tranche D notes.

 

The Company’s senior unsecured Tranche A, B and C notes are subject to prepayment penalties if repaid within three years of issuance. For any prepayments made on or prior to October 8, 2015, the Company must pay a make-whole amount equal to the present value of the interest payable on the principal balance of the prepaid notes from the date of prepayment through October 8, 2015, discounted at a rate equal to the yield to maturity for the applicable United States treasury securities plus 50 basis points. For any prepayments made on or before April 8, 2016, the Company must pay a prepayment premium equal to 3% of the principal amount repaid.

 

The Tranche D notes are subject to prepayment penalties if repaid on or before March 27, 2017. For any prepayments made on or prior to September 27, 2016, the Company must pay a make-whole amount equal to the present value of the interest payable on the principal balance of the prepaid Tranche D notes from the date of prepayment through September 27, 2016, discounted at a rate equal to the yield to maturity for the applicable

 

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United States treasury securities plus 50 basis point. For any prepayments made on or before March 27, 2017, the Company must pay a prepayment premium equal to 3% of the outstanding principal amount repaid.

 

During March 2014, the Company obtained a waiver that waived the application of the interest coverage, minimum production, total leverage and minimum liquidity financial covenants for the period ending March 31, 2014. During June 2014, the Company also obtained a waiver of the application of the interest coverage, minimum production, PDP asset coverage, proved reserves asset coverage and total leverage covenants for the period ended June 30, 2014. Additionally, the lenders amended the covenant ratio levels for the interest coverage, minimum production, PDP asset coverage, proved reserves asset coverage and total leverage financial covenants for the periods ending September 30, 2014, December 31, 2014 and March 31, 2015. In July 2014, the Company refinanced and replaced its senior unsecured notes. See Note 13Subsequent Events for discussion on the refinancing and replacement of the Company’s senior unsecured notes.

 

In connection with the issuance of the Tranche A and D notes, the Company issued to Highbridge and Apollo warrants to purchase an aggregate of 340,353 shares of its mandatory convertible preferred stock at an exercise price of $0.01 per share. 269,231 shares related to the issuance of the Tranche A notes in April 2013 and 71,122 shares related to the issuance of the Tranche D notes in March 2014. To objectively determine the fair market value of these warrants, ENXP engaged a third party valuation specialist to determine the fair market value of the series A and B preferred stock on the issue date of April 8, 2013 and March 27, 2014, respectively. Based on the Probability-Weighted Expected Return (“PWERM”) approach, the fair value of our series A and B preferred stock, on a minority, non-marketable basis, as of April 8, 2013 and March 27, 2014 was determined to be $51.12 per share and $51.27 per share resulting in a fair value of $13.8 million and $3.6 million for the warrants issued, respectively. These amounts were recorded as a discount to the value of the notes. The fair value on these warrants were measured at a fair value on a non-recurring basis using level 3 inputs. Each share of the preferred stock is convertible at the option of the holder prior to the Company’s initial public offering and will convert automatically upon completion of the initial public offering into one share of the Company’s common stock for an aggregate issuance of 340,353 common shares upon conversion of all preferred shares. To the extent not previously exercised, at the completion of the initial public offering, the warrants will automatically be exercised on a net basis for the number shares of the Company’s common stock calculated as the shares of preferred stock issuable upon exercise of the warrants that would have been converted less a number of shares equal to the aggregate exercise price divided by the initial public offering price per share.

 

Term Loan

 

In August 2013, ENXP entered into an agreement with Highbridge and Apollo for a $75 million Term Loan. As of June 30, 2014 this agreement was still subject to approval from the limited partner’s advisory committee of Highbridge. As of June 30, 2014, the Company had not drawn any amounts on the Term Loan.

 

In July 2014, the Company terminated the Term Loan agreement. See Note 13—Subsequent Events for discussion on the termination of the Company’s Term Loan.

 

Subordinated Unsecured Note—Chesapeake Note

 

In connection with the Chesapeake Acquisition during April 2013, ENXP issued an $18.0 million subordinated unsecured note to Chesapeake. The Chesapeake note matures on the earlier of (i) October 8, 2018, (ii) the closing of the Company’s initial public offering or (iii) six months after the date of repayment of the Company’s senior debt (as defined in the Chesapeake note) in full. The Chesapeake note bears interest at 10% per annum until the senior debt (as defined in the Chesapeake note) is paid in full and 15% thereafter. Until the senior debt (as defined in the Chesapeake note) is paid in full, all interest shall be paid in kind (“PIK”), with any such PIK interest being added to the principal balance of this note at the end of each quarter. The principal balance of this note plus all accrued and unpaid interest is expected to be paid within three business days after the maturity date. At June 30, 2014, including PIK interest, $20.3 million was payable on the Chesapeake note.

 

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Debt Issuance Costs

 

ENXP capitalizes certain direct costs associated with the issuance of long-term debt and amortizes to interest expense using the effective interest method such costs over the lives of the respective debt. During the six months ended June 30, 2014, the Company incurred $2.2 million in costs associated with the issuance of its outstanding debt and expensed $0.2 million of debt issuance costs. At December 31, 2013 and June 30, 2014, the Company had approximately $1.8 million and $3.8 million, respectively, of debt issuance costs remaining that are being amortized over the lives of the respective debts.

 

7. Share Based Compensation

 

On August 22, 2012, the Company’s sole director approved the ENXP 2012 Stock Incentive Plan (“the Plan”). The Plan enables the Board of Directors to award incentive and non-qualified stock options, restricted stock, unrestricted stock and restricted stock units to the Company’s officers, employees, directors, consultants, and key persons, including prospective employees conditioned on their employment. The maximum number of shares that may be issued under the Plan is 225,000, and as of June 30, 2014, 86,970 shares were available for future grants.

 

During the year 2014, the terms on certain awards issued under the Plan were modified. The modification included an extension of vesting dates and a change to the percentage of shares vesting at each vesting date. The following table summarizes the number of share awards and vesting dates for restricted shares granted:

 

     Tranche 1    Tranche 2    Tranche 3    Tranche 4

Shares awarded

   50,000    65,000    17,900    5,130

First Vesting Date

   August 15, 2014    IPO Date    IPO Date    September 30,2014

Second Vesting Date

         IPO Anniversary    September 30, 2015

Third Vesting Date

            September 30, 2016

 

Compensation recognized for grants vesting under the Plan was $5.8 million and $1.1 million for the six months ended June 30, 2013 and 2014, respectively. During the six months ended June 30, 2014, $0.7 million of the recognized compensation was recorded as share-based compensation and included in “General and administrative expenses” in the consolidated statement of operations and $0.4 million of the recognized compensation was recorded a capitalized employee related internal costs related to acquisition development and exploration activity and initially included in “Unproved oil and natural gas properties” on the consolidated balance sheet. Once unevaluated properties are evaluated all related unevaluated property costs, including capitalized share- based compensation, are transferred into “Proved oil and natural gas properties” to be amortized.

 

Total unrecognized compensation expense related to unvested options expected to be recognized over the remaining weighted vesting period of six months was $0.7 million at June 30, 2014. There was no change in the number of our non-vested shares issued under the plan during the six months ended June 30, 2014.

 

8. Derivative financial instruments

 

ENXP initiated a commodity derivative policy during 2013 to utilize various derivative instruments to hedge its exposure to oil and natural gas price fluctuations. Additionally, ENXP’s note purchase agreement and Term Loan agreement currently require the Company to enter into commodity derivative instruments for a minimum of 60% and maximum of 80% of anticipated production from its proved developed producing reserves. During the fourth quarter of 2013 and the first quarter of 2014, the Company entered into arrangements for fixed price swaps and costless collars (puts and calls) to hedge future oil and natural gas prices and comply with its debt instruments covenant requirements. ENXP has not designated any of its derivative instruments as hedges; therefore, the derivatives are carried at fair value on the consolidated balance sheets as assets or liabilities and all changes in fair value are recorded as gains and losses in the statements of operations in the periods in which they occur.

 

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ENXP’s derivative instruments expose the Company to credit risk in the event of nonperformance by counterparties. It is the Company’s policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive market makers. ENXP evaluates the credit standing of such counterparties by reviewing their credit rating. The counterparties to the Company’s current derivative agreements have investment grade ratings.

 

At June 30, 2014, ENXP had the following open oil and natural gas derivative contracts:

 

                                 Contract Price
($/Bbl or MMBtu)
Weighted Average Price
 

Year

   Months      Type of
Contract
     Pricing Index      Volume
(Bbl/d  or
MMBtu/d)
     Swap      Floor      Ceiling  

Crude Oil

                    

2014

     Jul – Dec         Swap         LLS         500       $ 96.24         —           —     

2014

     Jul – Dec         Swap         WTI         150       $ 95.55         —           —     

2015

     Jan – Dec         Collar         LLS         200         —         $ 81.00       $ 98.43   

2015

     Jan – Dec         Collar         WTI         150         —         $ 78.00       $ 96.10   

2016

     Jan – Dec         Collar         LLS         200         —         $ 71.75       $ 100.43   

Natural Gas

                    

2014

     Jul – Dec         Swap         NYMEX NG         500       $ 4.44         —           —     

 

Pursuant to the accounting standard that permits netting of assets and liabilities where the right of offset exists, ENXP presents the fair value of derivative financial instruments on a net basis by counterparty and commodity. The gross values, prior to netting of assets and liabilities subject to master netting arrangements, and the net amounts presented in the consolidated balance sheets as of December 31, 2013 and June 30, 2014 are as follows (in thousands):

 

     As of December 31, 2013  

Balance Sheet Location

   Gross Amounts
Recognized
     Gross Amounts
Offset on the
Balance Sheets
    Net Amounts
Presented on the
Balance Sheets
 

Assets

       

Current Asset—Derivative Asset

   $ 33       $ (33   $ —     

Long-term Assets—Derivative

     401         (401     —     
  

 

 

    

 

 

   

 

 

 

Total

     434         (434     —     

Liabilities

       

Current Liability—Derivative

     576         (33     543   

Long-term Liability—Derivative

     415         (401     14   
  

 

 

    

 

 

   

 

 

 

Total

     991         (434     557   
  

 

 

    

 

 

   

 

 

 

Net

   $ 557       $ —        $ 557   
  

 

 

    

 

 

   

 

 

 

 

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     As of June 30, 2014  

Balance Sheet Location

   Gross Amounts
Recognized
     Gross Amounts
Offset on the
Balance Sheets
    Net Amounts
Presented on the
Balance Sheets
 

Assets

       

Current Asset—Derivative Asset

   $ 29       $ (29   $ —     

Long-term Assets—Derivative

     154         (154     —     
  

 

 

    

 

 

   

 

 

 

Total

     183         (183     —     

Liabilities

       

Current Liability—Derivative

     1,459         (29     1,430   

Long-term Liability—Derivative

     587         (154     433   
  

 

 

    

 

 

   

 

 

 

Total

     2,046         (183     1,863   
  

 

 

    

 

 

   

 

 

 

Net

   $ 1,863       $ —        $ 1,863   
  

 

 

    

 

 

   

 

 

 

 

The following table summarizes the location and amounts of the Company’s realized gains and losses and changes in fair value of derivative contracts in the consolidated statements of operations (in thousands):

 

        At December 31,     At June 30,  

Derivatives not designated as hedging contracts

 

Location of gain or (loss) recognized in income on
derivative contracts

  2013     2014  

Oil Contracts:

     

Change in fair value of commodity

  Other income (expense)—Loss on derivatives   $ (557   $ (1,305

Realized loss on commodity contracts

  Other income (expense)—Loss on derivatives     (105     (851
   

 

 

   

 

 

 

Total loss on derivatives—oil

    $ (662   $ (2,156

Natural gas contracts:

     

Change in fair value of commodity contracts

  Other income (expense)—Loss on derivatives   $ —        $ (1

Realized loss on commodity contracts

  Other income (expense)—Loss on derivatives     —          (17
   

 

 

   

 

 

 

Total loss on derivatives—gas

    $ —        $ (18
   

 

 

   

 

 

 

Total loss on derivatives

    $ (662   $ (2,174
   

 

 

   

 

 

 

 

9. Fair value measures

 

The Company follows a framework for measuring fair value, which outlines a fair value hierarchy based on the quality of inputs used to measure fair value and enhances disclosure requirements for fair value measurements.

 

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Company uses market data, or assumptions that market participants would use, to value the asset or liability. These assumptions include market risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable.

 

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The Company primarily applies the market approach for recurring fair value measurements and attempt to use the best available information. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. This hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities, a Level 1 measurement, and lowest priority to unobservable inputs, a Level 3 measurement. The three levels of fair value hierarchy are as follows:

 

   

Level 1 inputs:    Unadjusted quoted prices in active markets for identical assets or liabilities accessible to the reporting entity at the measurement date. At December 31, 2013 and June 30, 2014, the Company had no level 1 measurement.

 

   

Level 2 inputs:    Pricing inputs other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Where observable inputs are available, directly or indirectly, for substantially the full term of the asset or liability, the instrument is categorized in level 2.

 

   

Level 3 inputs:    Unobservable inputs for the asset or liability used to measure fair value to the extent that observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at measurement date. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

 

Asset and Liabilities Measured at Fair Value on a Recurring Basis

 

ENXP accounts for commodity derivatives at fair value on a recurring basis. The Company’s commodity derivative instruments consist of swaps and costless collars. At December 31, 2013 and June 30, 2014, the Company estimated the fair value of its derivative instruments based on published forward commodity price curves as of the date of the estimate, less discounts to recognize present values using a pricing model which also considered market volatility, counterparty credit risk and additional criteria in determining discount rates. The discount rate used in the discounted cash flow projections was based on published LIBOR rates, Eurodollar futures rates and interest swap rates. The counterparty credit risk was determined by calculating the difference between the derivative counterparty’s bond rate and published bond rates.

 

The following tables summarize by level within the fair value hierarchy, the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2013 and June 30, 2014 (in thousands):

 

     Fair Value Measurements Using:  
     Quoted Prices in
Active Markets
(Level 1)
     Significant Other
Observable Inputs
(Level 2)
    Significant
Unobservable
Inputs
(Level 3)
     Total  

December 31, 2013

          

Liabilities:

          

Derivative contracts—current

   $ —         $ (543   $ —         $ (543

Derivative contracts—long-term

     —           (14     —           (14
  

 

 

    

 

 

   

 

 

    

 

 

 

Total Liabilities

   $ —         $ (557   $ —         $ (557
  

 

 

    

 

 

   

 

 

    

 

 

 

June 30, 2014

          

Liabilities:

          

Derivative contracts—current

   $ —         $ (1,430   $ —         $ (1,430

Derivative contracts—long-term

     —           (433     —           (433
  

 

 

    

 

 

   

 

 

    

 

 

 

Total Liabilities

   $ —         $ (1,863   $ —         $ (1,863
  

 

 

    

 

 

   

 

 

    

 

 

 

 

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Since the Company does not use hedge accounting for its commodity derivative contracts, any gains and losses on its assets and liabilities are included in “Loss on derivatives” in the accompanying consolidated statements of operations.

 

Asset and Liabilities Measured at Fair Value on a Nonrecurring Basis

 

ENXP follows the provisions of ASC 820-10, for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. This statement applies to the initial recognition of asset retirement obligations for which fair value is used.

 

The Company estimates the fair value of its ARO based on historical costs, discounted cash flow projections using numerous estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an ARO, amounts and timing of settlements, the credit-adjusted risk-free rate to be used, inflation rates as well as management’s expectation of future cost environments. As there are no corroborating market activity to support the assumptions, the Company has designated these liabilities as level 3. A reconciliation of the beginning and ending balances of the Company’s ARO is presented in Note 5—Asset Retirement Obligations.

 

Other Fair Value Measurements

 

ENXP has other financial instruments consisting primarily of cash, cash equivalents, short-term receivables and payables that approximate fair value due to the nature of the instrument and the relative short maturities.

 

10. Income Taxes

 

Income tax benefit (provision)

 

The Company estimates its federal and state income tax provision based on current tax law. The reported tax provision differs from the amounts currently receivable or payable because certain income and expense items are recognized in different time periods for financial reporting purposes than for income tax purposes. The following is a summary of the Company’s benefit (provision) for income taxes (in thousands):

 

     Six Months Ended
June 30,
 
         2013              2014      

Current

     

Federal

   $ 4,202       $ (162

State

     11         (44
  

 

 

    

 

 

 
     4,213         (206

Deferred

     

Federal

     595         —     

State

     17         —     
  

 

 

    

 

 

 
     612         —     
  

 

 

    

 

 

 

Income tax benefit(expense)(1)

   $ 4,825       $ (206
  

 

 

    

 

 

 

 

(1)   Excludes $0.9 million of tax penalties and interest incurred during the six months ended June 30, 2013 and $0.5 million benefit related to the reversal of accrued tax penalties and interest during the six months ended June 30, 2014 related to delinquent tax filings for the 2012 tax year.

 

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The Company’s income tax provision is based on its results of operations. The Company has recorded deferred federal and state income tax assets and liabilities attributable to the differences in the bases in its assets for U.S. GAAP and for federal and state taxation purposes upon our conversion to a C Corporation. A reconciliation of the statutory federal tax provision to the Company’s income tax provision in the accompanying financial statements is as follows (in thousands):

 

     Six Months Ended
June 30,
 
     2013     2014  

Statutory federal provision (35%)

   $ 4,988      $ 1,076   

Statutory state income tax provision, net of federal tax benefit

     86        (23

Return to provision adjustment

     83        (161

Change in valuation allowance .

     —          (1,105

Tax effect of expenses not deductible for federal or state taxation

     (332     7   
  

 

 

   

 

 

 

Income tax benefit (expense) before tax penalties and interests

   $ 4,825      $ (206

Penalties and interests(1)

     (903     548   
  

 

 

   

 

 

 

Income tax benefit

   $ 3,922      $ 342   
  

 

 

   

 

 

 

 

(1)   Penalties and interest on 2012 late tax filing for the six month periods ended June 30, 2013 and reversal of accrued penalties and interest on 2012 late tax filing during the period ended June 30, 2014.

 

The Company recognizes interest and penalties accrued to unrecognized benefits in income tax benefit (expense) in its consolidated statements of operations. For the six month periods ended June 30, 2013 and 2014 and the years ended December 31, 2013, 2012 and 2011, the Company recognized no interest and penalties related to unrecognized benefits.

 

As of June 30, 2014, the Company has available, to reduce future taxable income, a United States net operating loss carryforward (NOLs) of approximately $38.2 million, portions of which begin to expire in the year 2033. No portion of the net operating loss carryforward is subject to the ownership change limitation provisions of Section 382 of the Internal Revenue Code (IRC).

 

The Company assesses the recoverability of its deferred tax assets each period by considering whether it is more likely than not that all or a portion of the deferred tax assets will not be realized. The Company considers all available evidence (both positive and negative) in determining whether a valuation allowance is required and adjusts the valuation allowance as required based on information available together with managements judgment regarding the appropriate level of valuation allowance to be provided against existing deferred tax assets. At the end of the six months ended June 30, 2014, the Company has increased the valuation allowance by $1.1 million based on current expectations related to realizability of its net deferred tax assets.

 

On September 13, 2013, the United States Treasury Department and the Internal Revenue Service issued final tangible property regulations (the tangible property regulations) under provisions that include IRC Sections 162, 167 and 263(a). The tangible property regulations apply to amounts paid to acquire, produce or improve tangible property, as well as dispositions of such property. The general effective date of the tangible property regulations are for tax years beginning on or after January 1, 2014. Based on the Company’s analysis to date management does not anticipate the impacts of the tangible property regulations to be material to the Company’s consolidated financial position or its results of operations, or both.

 

11. Earnings Per Share

 

Earnings (Loss) Per Share.    The two-class method of computing net earnings per share is required for those entities that have participating securities. The two-class method is an earnings allocation formula that determines net earnings per share for participating securities according to dividends declared (or accumulated) and participation rights in undistributed earnings. ENXP’s restricted shares of common stock, See Note 7—Share

 

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based compensation for additional discussion, are participating securities under ASC 260, Earnings Per Share, because they may participate in undistributed earnings with common stock.

 

The following table shows the computation of basic and diluted net loss per share for the six months ended June 30, 2013 and 2014 (in thousands, except for share and per share amounts):

 

     Six Months Ended
June 30,
 
     2013     2014  

Net loss

   $ (9,432   $ (3,282
  

 

 

   

 

 

 

Weighted average number of shares used to calculate basic and Per share:

    

Weighted average number of unrestricted outstanding

     372,500        372,500   

Effect of unvested restricted stock awards

     128,568        138,030   
  

 

 

   

 

 

 

Denominator for basic loss per common share

     501,068        510,530   

Dilutive effect of warrants(1)

     —          —     
  

 

 

   

 

 

 

Denominator for diluted earnings per common share

     501,068        510,530   
  

 

 

   

 

 

 

Net loss per common share:

    

Basic

   $ (18.82   $ (6.43

Diluted:

   $ (18.82   $ (6.43

 

(1)   The potentially dilutive impact of the warrants to purchase 124,145 and 306,560 shares of our mandatory redeemable preferred stock for the six months ended June 30, 2013 and 2014, respectively, were excluded from this calculation as they were antidilutive.

 

12. Commitments and Contingencies

 

The Company’s contractual obligations include notes payable, operating lease obligations related to office space, certain vehicles, and office equipment, and asset retirement obligations. During the six months ended June 30, 2014, there were no material changes to the Company’s contractual obligations, other than changes related to its senior unsecured notes. Rental expense pursuant to office leases amounted to $0.1 million and $0.2 million for the six months ended June 30, 2013 and 2014 respectively. Other contractual obligations are consistent with the December 31, 2013 levels and contain various expiration dates through 2019. We had the following contractual obligations and commitments as of June 30, 2014 (in thousands):

 

    Obligations and Commitments Due By Period  
    Total     2014     2015     2016     2017     2018     Thereafter  

Senior unsecured notes

  $ 225,000      $ —        $ —        $ —        $ —        $ 180,000      $ 45,000   

Subordinated Chesapeake note(1)

    30,798        —          —          —          —          30,798        —     

Interest expense on senior unsecured notes

    151,099        17,081        34,219        34,313        39,496        23,840        2,150   

Contractual lease payments

    786        233        455        88        10        —          —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total contractual obligations

  $ 407,683      $ 17,314      $ 34,674      $ 34,401      $ 39,506      $ 234,638      $ 47,150   
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)   Includes $12.8 million of interest paid or to be paid in kind.

 

Litigation

 

ENXP, from time to time, is involved in various claims, lawsuits, and disputes with third parties, actions involving allegations of fraud, discrimination, or breach of contract incidental to operations of its business. The Company is not currently involved in any litigation which management believes could have a materially adverse effect on its financial condition or results of operations.

 

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13. SUBSEQUENT EVENTS

 

Acquisitions

 

On July 22, 2014, effective April 1, 2014, the Company and TreadStone Energy Partners, LLC, a Delaware limited liability company, closed on a transaction for the Company to purchase oil and gas leasehold, a salt water disposal system, 3D seismic and producing wells in Houston and Madison Counties, Texas, (the “Ft. Trinidad acquisition”) for an initial cash purchase price of $719.1 million, subject to post-closing customary purchase price adjustments. Subsequent to closing, the Company recognized net negative post-closing adjustments of $25.8 million for a cash purchase price of $693.3 million. The purchase price is subject to additional post-closing adjustments as revenue and expenditures are received and processed.

 

The acquisition was accounted for as a business combination in accordance with the Accounting Standards Codification (“ASC”) No 805 “Business Combinations” which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition date fair values.

 

The purchase price allocation presented below is preliminary and includes the use of estimates. The preliminary allocation is based on information that was available to management at the time these unaudited consolidated financial statements were prepared and is subject to change as additional information becomes available and the final post-closing settlement occurs 120 days subsequent to the initial closing of the acquisition. The following table summarizes the consideration paid to acquire the properties and the amounts of the assets acquired and liabilities assumed as of the initial closing on the acquisition date and post-closing adjustments recognized as of August 31, 2014. (in thousands):

 

Purchase Price

 

Purchase price—net cash consideration paid to sellers

   $ 693,260   

Liabilites assumed:

  

Accounts payable and other liabilities

     6,628   

Long-term asset retirement obligation

     2,631   
  

 

 

 

Total purchase price plus liabilities assumed

   $ 702,519   
  

 

 

 

 

Estimated Fair Value of Assets Acquired and Assumed

 

Proved oil and natural gas properties

   $ 702,068   

Accounts receivable—other

     451   
  

 

 

 

Attributable to assets acquired and assumed

   $ 702,519   
  

 

 

 

 

The estimated fair value of the proved oil and natural gas properties acquired was determined using Level 3 input assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for the timing and amount of future development costs, operating costs, abandonment costs, projections of future rates of production, expected recovery rates and risks adjusted discount rates.

 

The fair value of the asset retirement obligation was determined using level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging, abandonment and remediation costs, inflation rate and well life.

 

Contemporaneous with the closing of the Ft. Trinidad acquisition, the Company completed a financing consisting of a $775 million senior secured term loan and the issuance of $375 million of convertible notes. The Company used a portion of the net proceeds of the debt issuances to fund the Ft. Trinidad acquisition and to refinance and replace its previously outstanding senior unsecured notes. The Ft. Trinidad acquisition, the debt issuances and the debt retirement are all reflected in the pro forma financial information included below. The following unaudited pro forma combined results of operations are provided for the six-month periods ended June 30, 2013 and June 30, 2014 as though the transactions occurred as of the beginning of the earliest period presented, or January 1, 2013.

 

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The unaudited pro forma combined and consolidated condensed statement of operations are presented for illustrative purposes only and are not necessarily indicative of the consolidated financial position or consolidated results of operations of the Company that would have been reported had the transactions occurred on the dates indicated, nor do they represent a forecast of the consolidated results of operations of the Company at any future date. Additionally, non-recurring debt extinguishment costs of $76.7 million, including a prepayment penalty, have been excluded from the pro forma results.

 

     Six Months ended June 30,  
           2013                 2014        

Revenue

   $ 29,085      $ 118,889   

Net income (loss)

     (38,995     3,319   

Income (loss) available to common shareholders

     (38,995     3,319   

Pro forma net loss per common share

    

Basic

   $ (77.82   $ 6.50   

Diluted

   $ (77.82   $ 4.06   

 

The following adjustments were made in the preparation of the pro forma combined and consolidated condensed statement of operations:

 

   

Revenues and operating expenses for the Ft. Trinidad properties were derived from the historical records of the seller.

 

   

Depreciation, depletion and amortization expense was estimated using the full-cost method and determined by including the purchase price allocation, future development costs, production and reserves for the acquired assets.

 

   

Accretion expense was computed using the Company’s estimate of asset retirement obligations for the acquired assets using calculation methods described in Note 5.

 

   

Interest expense was computed using contractual interest rates on the new convertible notes and senior secured term loan credit facility and includes amortization of debt discounts and debt issuance costs. See below for additional discussion on the terms of the convertible notes, the senior secured term loan credit facility and the retirement of the senior unsecured notes.

 

Convertible Notes

 

On July 22, 2014, contemporaneously with the closing of the Ft. Trinidad acquisition and the senior secured term loan, the Company issued $375 million of its 8.0% convertible subordinated notes due 2019 (the “Notes”) in a private placement transaction. The net proceeds of the Notes offering, along with the net proceeds from the senior secured term loan, were used to fund the Ft. Trinidad acquisition and to refinance and replace the Company’s senior unsecured notes. The refinancing and replacement of the Company’s senior unsecured notes were accounted for as the extinguishment of debt for accounting purposes.

 

The $375.0 million principal amount of Notes were issued net of $22.4 million debt origination costs and $74.7 million fair value of embedded derivative. The Notes contain a conversion feature allowing holders to convert all or part of the Notes into shares of the Company’s common stock upon the closing of a qualified public offering. The Notes also contain a put option feature allowing holders to require the Company to repurchase for cash all or a part of the outstanding Notes if the Company undergoes a change of control. The embedded features meet the definition of a derivative under ASC 815 and require bifurcation and are accounted for as a separate combined embedded derivative. Therefore, initially the embedded derivative will be recorded on the balance sheet as a derivative liability at its estimated fair value of $74.7 million and will create a discount on the Notes that will be amortized over the life of the Notes using the effective interest rate method. The fair value of the embedded derivative will be measured and recorded at each subsequent reporting period and changes in fair value will be recognized in the statement of operations as a gain or loss on derivative. The estimated fair market value of the Company’s embedded derivative could change significantly based on future market conditions.

 

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The Company has estimated the fair market value of the embedded derivatives of the Notes as the difference between the fair market value of the Notes with all contractual features and the fair market value of the Notes without the contractual features associated with the embedded derivative, in both cases using relevant market data.

 

In the case of the fair market value of the Notes with all contractual features, the Hybrid Method was used utilizing probability-weighted expected return method combined with the option price method. In the case of the fair market value of the Notes without those contractual features associated with the embedded derivative, a discounted cash flow approach was used.

 

The key valuation assumptions used consist of the Company’s equity value, Management’s estimate of various exit scenarios and their probabilities, and expected volatility based on peer companies and adjusted for leverage. The Company considers these inputs Level 3 assumptions.

 

The difference in the estimated fair market value of the Notes with all contractual features and the estimated fair market value of the Notes without those contractual features associated with the embedded derivative represents the estimated fair value of the embedded derivative of $74.7 million at inception.

 

The Notes bear interest at a rate of 8.0% per annum subject to semi-annual increases of 0.50% beginning on July 1, 2015 if a preliminary prospectus under the Securities Act with a bona fide price range in connection with a qualified public offering (as defined below) has not been filed by each such date and, in each case, the qualified public offering has not priced within 60 days after the date of such scheduled interest rate increase. The Company does not believe the contingent interest rate increases are probable, and therefore the contingent interest has not been included in the pro forma effective interest calculation. The Company will continue to access the probability related to the contingent interest for recognition and measurement on a quarterly basis.

 

Holders of the Notes may elect to convert their notes into shares of the Company’s common stock at a specified conversion price in connection with the closing of a qualified public offering. A qualified public offering is defined as the first public offering of the Company’s common stock in which the aggregate gross proceeds to the Company and any selling stockholders equals or exceeds $400.0 million and following which the Company’s common stock is listed on a U.S. national securities exchange.

 

The number of shares of common stock issuable upon conversion of the Notes will be the greater of:

 

   

the number of shares of common stock determined by dividing (1) the principal amount of the Notes converted by (2) a conversion price that is equal to a specified percentage of the public offering price per share in the qualified public offering that decreases over time, which percentage will be 90% assuming a qualified public offering is consummated on or before December 31, 2014; and

 

   

a number of shares of common stock that represents a percentage of the Company’s outstanding shares of common stock immediately prior to the consummation of a qualified public offering (giving effect to the conversion of the Notes and all other securities that are convertible into shares of the Company’s common stock, but before the issuance by the Company of shares in the qualified public offering) that is equal to (1) the principal amount of the Notes converted divided by (2) $900 million.

 

Holders of the Notes may elect to convert their Notes during the period commencing on the first business day after the filing of a registration statement for a qualified public offering and ending on a date not less than 30 business days thereafter to be set by the Company. Following the completion of a qualified public offering, the Company will redeem any Notes not converted at a price equal to 100% of the principal amount of the Notes redeemed, plus accrued interest.

 

Holders of the Notes have certain registration rights with respect to the shares of common stock issuable upon conversion of the Notes, including piggyback registration rights that permit holders to sell up to an aggregate 36% of those shares of common stock in a qualified public offering.

 

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Senior Secured Term Loan

 

On July 22, 2014, contemporaneously with the closing of the Ft. Trinidad acquisition and the offering of the Notes, the Company entered into the agreement governing the senior secured term loan with a group of institutional lenders and borrowed $775.0 million under the senior secured term loan. The senior secured term loan matures on January 22, 2019 and provided for an original principal amount of $775.0 million issued at an original issue discount of 1.5%, or $11.6 million, and included debt issuance costs of approximately $16.4 million, including a 2.125% arrangement fee of $15.7 million, on $740.0 million of the principal amount. Subject to certain conditions, including obtaining the participation of existing or prospective lenders, the Company may incur incremental term loans in an amount up to $175.0 million. The proceeds from the senior secured term loan were used, together with the proceeds of the Notes, to pay the purchase price for the Ft. Trinidad acquisition and to refinance and replace the Company’s existing senior unsecured notes. The refinancing and replacement of the Company’s existing senior unsecured notes were accounted for as the extinguishment of debt for accounting purposes.

 

The Company’s wholly owned subsidiary, Energy & Exploration Partners, LLC (“ENXP LLC”), is the borrower under the senior secured term loan. The Company and each of ENXP LLC’s subsidiaries guarantee the obligations of ENXP LLC under the senior secured term loan. The Company’s obligations under the senior secured term loan are secured by a pledge of its equity interests in ENXP LLC and substantially all of ENXP LLC’s and its subsidiaries’ assets, including a perfected mortgage lien on oil and gas properties that represent at least 80% of the present value in the Company’s reserve report.

 

The senior secured term loan bears interest at variable rates, at the Company’s option, (x) based on the greater of (a) the London interbank offered rate times the statutory reserves and (b) 1% (in either case the “Adjusted LIBOR”), plus 6.75%, or (y) the greatest of (a) the prime rate, (b) the federal funds effective rate plus  1/2 of 1%, and (c) the Adjusted LIBOR for one month, plus 5.75%. The Company is required to repay the senior secured term loan quarterly, in the principal amount of $1.9 million, plus accrued and unpaid interest, with the balance due at maturity.

 

The Company may prepay the senior secured term loan, in whole or in part, at any time subject to an applicable premium (x) in year 1, of 2% of the principal repaid, (i) in year 2, of 1% of the principal repaid, and (ii) on and after the second anniversary of the closing date, no premium. Subject to certain exceptions, the Company is required to prepay any loans outstanding under the senior secured term loan by an amount equal to: (x) 100% of the net cash proceeds of certain asset dispositions, (y) 50% of the excess cash flow for any fiscal year, subject to reduction to 25% or 0% in the event certain leverage ratios are achieved and (z) 100% of the net cash proceeds of the issuance of unpermitted debt. The Company and ENXP LLC may also repurchase the senior secured term loan from one or more lenders in the open market or pursuant to Dutch auction procedures, subject to the satisfaction of certain conditions.

 

Subject to certain exceptions and baskets, the agreement governing the senior secured term loan contains customary restrictive covenants that, among other things

 

   

limit the Company’s incurrence of additional indebtedness, other than the Chesapeake note, the Convertible note, any intercompany indebtedness currently existing and any permitted refinance indebtedness other than certain exceptions;

 

   

prohibit the granting of liens, other than certain permitted liens;

 

   

limit the Company’s ability to make or permit to remain outstanding any investments in or to any person subject to certain exceptions;

 

   

prohibit mergers, consolidations and sales of all or a part of the Company’s assets, or issue equity interest in any subsidiary, or purchase, lease or otherwise acquire all or any substantial part of the assets of any other persons subject to certain exceptions;

 

   

prohibit the declaration or agreement to declare or make directly or indirectly, any restricted payment, or incur any obligation to do so subject to certain provisions and exceptions;

 

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require the Company to meet a maximum leverage ratio of (x) 4.50 to 1.00 for the fiscal quarters ending December 31, 2014 through and including September 30, 2015 and (y) 3.00 to 1.00 for the fiscal quarter ending December 31, 2015 and each fiscal quarter thereafter, tested on a quarterly basis; and

 

   

require the Company to enter into commodity derivative instruments for a minimum of 40% and maximum of 80% of anticipated production from its proved reserves.

 

The agreement provides for customary events of default, subject to applicable grace periods.

 

Retirement of Senior Unsecured Notes

 

The Company used a portion of the net proceeds of the Notes offering, along with the net proceeds from the senior secured term loan, to refinance and replace its senior unsecured notes. The Company incurred a loss on extinguishment of debt of approximately $76.7 million relating to a $52.6 million prepayment penalty and the expensing of $24.1 million of unamortized discounts and debt issuance costs.

 

Other Events

 

Management has evaluated subsequent events through September 12, 2014, the date these condensed consolidated financial statements were available to be issued. No events or transactions other than those already described in these financial statements have occurred subsequent to the balance sheet date that might require recognition or disclosure in the condensed consolidated financial statements.

 

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

To the Board of Directors and Stockholders of:

Energy & Exploration Partners, Inc.

 

We have audited the accompanying consolidated balance sheets of Energy & Exploration Partners, Inc., as described in Note 2, (the “Company”) as of December 31, 2013 and 2012, and the related consolidated statements of operations, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2013. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

 

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

 

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Energy & Exploration Partners, Inc. as of December 31, 2013 and 2012, and the results of its operations and cash flows for each of the three years in the period ended December 31, 2013, in conformity with U.S. generally accepted accounting principles.

 

/s/ Hein & Associates LLP

Dallas, Texas

April 4, 2014

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

CONSOLIDATED BALANCE SHEETS

(In thousands, except par value and share amounts)

 

     December 31,
2012
    December 31,
2013
 
ASSETS     

Current assets:

    

Cash and cash equivalents

   $ 10,228      $ 3,569   

Debt service deposits

     4,200        —     

Accounts receivable-oil and natural gas sales

     59        4,816   

Accounts receivable-other

     1,618        —     

Deferred tax assets

     —          271   

Prepaid expenses

     3,823        617   
  

 

 

   

 

 

 

Total current assets

     19,928        9,273   

Property, plant, and equipment:

    

Unproved oil and natural gas properties

     31,175        89,086   

Proved oil and natural gas properties

     6,059        158,955   

Other property and equipment

     711        979   

Less: Accumulated depreciation, depletion and amortization

     (4,497     (19,763
  

 

 

   

 

 

 

Net property, plant, and equipment

     33,448        229,257   

Long-term assets:

    

Loan origination fees, net of amortization of $278 and $179, respectively

     1,014        1,782   

Deferred tax assets

     1,255        —     

Long-term deposits

     10,045        87   

Other long-term assets

     2,384        3,174   
  

 

 

   

 

 

 

Total long-term assets

     14,698        5,043   
  

 

 

   

 

 

 

TOTAL ASSETS

   $ 68,074      $ 243,573   
  

 

 

   

 

 

 
LIABILITIES AND STOCKHOLDERS’ EQUITY     

Current liabilities:

    

Accounts payable

   $ 2,143      $ 29,319   

Accrued and other liabilities

     7,065        12,133   

Accrued interest

     274        58   

Deposit for investments

     22        22   

Deposit for investment-related party

     22        22   

Derivative liability

     —          543   

Asset retirement obligation

     —          655   

Current note payable

     7,102        —     

Current income tax liability

     8,536        1,298   

Deferred tax liability

     139        —     
  

 

 

   

 

 

 

Total current liabilities

     25,303        44,050   

Asset retirement obligation

     16        637   

Deferred tax liability

     —          271   

Derivative liability

     —          14   

Notes payable, net of discount of $0 and $16,006, respectively

     14,191        168,336   
  

 

 

   

 

 

 

Commitments and contingencies (Note 13)

    

Total liabilities

     39,510        213,308   

Preferred stock, $0.01 par value; 750,000 shares authorized; no shares issued or outstanding

     —          —     

Common stock, $0.01 par value; 1,200,000 shares authorized, 500,000 and 510,530 shares issued and outstanding, at December 31, 2012 and 2013

     5        5   

Additional paid-in capital

     19,162        42,629   

Retained earnings (deficit)

     9,397        (12,369
  

 

 

   

 

 

 

Total stockholders’ equity

     28,564        30,265   
  

 

 

   

 

 

 

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY

   $ 68,074      $ 243,573   
  

 

 

   

 

 

 

 

See accompanying notes to these consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands, except share and per share amounts)

 

     Year Ended December 31,  
     2011     2012     2013  

Revenues:

      

Oil and natural gas sales

   $ —        $ 216      $ 16,437   

Operating expenses:

      

Lease operating expense

     —          11        3,215   

Production taxes

     —          14        866   

Impairment and abandoment of unproved properties

     679        —          —     

Full-cost ceiling impairment

     —          3,957        8,447   

General and administrative expense

     1,069        10,538        16,888   

Depreciation, depletion and amortization

     29        469        6,917   
  

 

 

   

 

 

   

 

 

 

Total operating expenses

     1,777        14,989        36,333   
  

 

 

   

 

 

   

 

 

 

Loss from operations

     (1,777     (14,773     (19,896

Other income (expense):

      

Interest and other income

     25        10        53   

Loss on early extinguishment of debt

     —          (985     (3,677

Interest expense

     (270     (2,842     (17,211

Loss on derivatives

     —          —          (662

Gain on sales of assets

     573        34,738        14,275   
  

 

 

   

 

 

   

 

 

 

Total other income (expense), net

     328        30,921        (7,222
  

 

 

   

 

 

   

 

 

 

Income (loss) before income tax expense

     (1,449     16,148        (27,118

Income tax benefit (expense)

     (29     (7,414     5,351   
  

 

 

   

 

 

   

 

 

 

Net income (loss)

   $ (1,478   $ 8,734      $ (21,767
  

 

 

   

 

 

   

 

 

 

Basic and dilutive:

      

Net income (loss) attributable to common stock—Basic and diluted

   $ (3.72   $ 20.12      $ (43.12

Weighted average shares of common stock outstanding—Basic and diluted

     397,500        434,187        504,796   

 

See accompanying notes to these consolidated financial statements.

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

 

(In thousands, except share amounts)

 

     Member’s equity of
Energy &
Exploration(1)
    Controlling interest
of NASIF(2)
     Non-controlling
interests of
NASIF(3)
    Common
stock shares
    Common
stock,
par value
     Additional
paid in
capital
     Retained
earnings
(deficit)
    Total
equity
 

TOTAL STOCKHOLDERS’ EQUITY

                   

January 1, 2011

   $ 5,669      $ —         $ —        $ —        $ —         $ —         $ —        $ 5,669   

Contributions

     326        —           10,600        —          —           —           —          10,926   

Distributions

     (46     —           —          —          —           —           —          (46

Net loss prior to reorganization

     (1,478     —           (135     —          —           —           —          (1,613
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

TOTAL STOCKHOLDERS’ EQUITY

                   

December 31, 2011

   $ 4,471      $ —         $ 10,465      $ —        $ —         $ —         $ —        $ 14,936   
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

Distributions

     (150     —           —          —                  (150

Net loss prior to reorganization

     (571     —           (92     —                  (663

Formation

     —          —           —          1,000                —     

Reorganization

     (3,750     —           (10,373     396,500        4         15,301           1,182   

Equity owner contribution

       —             (22,500     —           —             —     

Share-based compensation awards

       —             125,000        1         3,861           3,862   

Net income after reorganization

                 —           9,397        9,397   
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

TOTAL STOCKHOLDERS’ EQUITY

                   

December 31, 2012

     —        $ —         $ —          500,000      $ 5       $ 19,162       $ 9,397      $ 28,564   
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

Equity owner contribution

            (2,500     —           —           —          —     

Share-based compensation awards

            13,030        —           9,704         —          9,704   

Warrant issuance

            —          —           13,763         —          13,763   

Net loss

            —          —           —           (21,767     (21,767
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

TOTAL STOCKHOLDERS’ EQUITY

                   

December 31, 2013

   $ —        $ —         $ —          510,530      $ 5       $ 42,629       $ (12,369   $ 30,265   
  

 

 

   

 

 

    

 

 

   

 

 

   

 

 

    

 

 

    

 

 

   

 

 

 

 

(1)   Represents members equity of Energy & Exploration Partners, LLC, Energy & Exploration Partners Operating GP, LLC and Energy & Exploration Partners Operating, LP
(2)   Represents members equity of North American Shale Investment Fund GP, LP, North American Shale GP, LLC and North American Shale Investment Advisors, LLC
(3)   Represents non-controlling interests of North American Shale Investment Fund GP, LP, North American Shale GP, LLC and North American Shale Investment Advisors, LLC.

 

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ENERGY & EXPLORATION PARTNERS, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

 

     Year Ended December 31,  
     2011     2012     2013  

Cash flows from operating activities:

      

Net income (loss)

   $ (1,478   $ 8,734        (21,767

Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities

      

Gain on sales of oil and natural gas assets

     (573     (34,738     (14,275

Impairment and abandonment of unproved properties

     679        —          —     

Full-cost ceiling impairment

     —          3,957        8,447   

Depreciation, depletion and amortization

     29        469        6,917   

Non-cash interest and amortization of debt costs

     109        (417     4,590   

Gain on the forgiveness of liabilities

     (21     —          —     

Share based compensation award

     —          3,862        9,704   

Unrealized commodity derivatives loss

     —          —          557   

Loss on early extinguishment of debt

     —          985        3,677   

Deferred tax assets

     —          —          1,116   

Adjustments to working capital to arrive at net cash used in operating activities:

      

Accounts receivable

     70        (740     (3,139

Prepaid expenses

     (24     (3,799     3,206   

Income taxes

     —          (1,116     —     

Accounts payable- related party

     34        2        (2

Current income tax liability

     —          8,536        (7,238

Accounts payable, accrued and other liabilities

     171        3,193        28,153   
  

 

 

   

 

 

   

 

 

 

Net cash provided by (used in) operating activities

     (1,004     (11,072     19,946   

Cash flows from investing activities:

      

Acquisition of Chesapeake oil and gas properties

     —          —          (68,875

Oil and natural gas capital expenditures

     (18,913     (55,126     (115,174

Proceeds from the sale of oil and gas properties, net of transaction costs

     1,129        75,155        19,875   

Acquisition of furniture, fixtures, and equipment

     (59     (577     (268

Deposit for lease acquisition

     (25     (6,500     —     

Purchase of security deposits

     —          (41     (40
  

 

 

   

 

 

   

 

 

 

Net cash provided by (used in) investing activities

     (17,868     12,911        (164,482

Cash flows from financing activities:

      

Proceeds from owners

     137        —          —     

Distributions to equity owners

     (46     (150     —     

Proceeds from notes payable, net of debt service deposits funded

     9,300        30,286        160,241   

Payments on notes payable, net of debt service deposits returned

     —          (22,493     (17,284

Payment of costs associated with early extinguishment of debt

     —          —          (2,779

Payments of deferred offering costs

     —          (1,714     (340

Payments of loan origination costs

     (234     (1,292     (1,961

Proceeds from investment deposits

     12,577        —          —     

Repayments of investment deposits

     (30     (1,520     —     

Repurchase of warrants

     —          (125     —     
  

 

 

   

 

 

   

 

 

 

Net cash provided by financing activities

     21,704        2,992        137,877   
  

 

 

   

 

 

   

 

 

 

Net change in cash and cash equivalents

     2,832        4,831        (6,659

Cash and cash equivalents at beginning of period

     2,565        5,397        10,228   
  

 

 

   

 

 

   

 

 

 

Cash and Cash equivalents at end of period

   $ 5,397      $ 10,228      $ 3,569   
  

 

 

   

 

 

   

 

 

 

Supplemental disclosure of cash flow information:

      

Cash paid for interest

   $ 156      $ 2,406      $ 19,606   
  

 

 

   

 

 

   

 

 

 

Cash paid for taxes

   $ —        $ —        $ 709   
  

 

 

   

 

 

   

 

 

 

Non-cash investing and financing activities:

      

Non-cash capitalized interest

     —          —          252   
  

 

 

   

 

 

   

 

 

 

Payment-in-kind interest

     —          —          1,342   
  

 

 

   

 

 

   

 

 

 

Contribution of shares by equity owner

   $ —        $ 2,858      $ —     
  

 

 

   

 

 

   

 

 

 

Original issue discount on notes payable

   $ —        $ —        $ 4,200   
  

 

 

   

 

 

   

 

 

 

Warrants issued in conjunction with notes payable

   $ —        $ —        $ 13,763   
  

 

 

   

 

 

   

 

 

 

Asset Retirement Obligations

   $ —        $ 15      $ 1,292   
  

 

 

   

 

 

   

 

 

 

 

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ENERGY & EXPLORATION PARTNERS, INC.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

1. Organization

 

Energy & Exploration Partners, Inc. (together with our consolidated subsidiaries, “ENXP,” “the Company,” “we,” “our,” “us” or similar terms) was incorporated pursuant to the laws of the State of Delaware in July 2012. ENXP is an independent exploration and production company focused on the acquisition, exploration, development and exploitation of unconventional oil and natural gas resources. The Company has undeveloped leasehold acres in three core areas: the eastern expansion of the Eagle Ford Shale in East Texas referred to as the Woodbine or “Eaglebine” formation; the Wolfcamp Shale in the Permian Basin in West Texas (“Wolfcamp”); and the Niobrara formation in the Denver Julesburg Basin in Wyoming (“Niobrara”). The Company focuses on liquids-rich resource plays and believes that a substantial portion of its acreage is oil-prone. The Company plans to continue to pursue additional leasehold acquisitions in its Eaglebine core area and pursue other emerging opportunities.

 

2. Summary of Significant Accounting Policies

 

Corporate Reorganization

 

On August 22, 2012, the Company’s equity owner contributed all of his interest in Energy & Exploration Partners, LLC, Energy & Exploration Partners Operating, LP, and Energy & Exploration Partners Operating GP, LLC to Energy & Exploration Partners, Inc., for the majority of the common stock of Energy & Exploration Partners, Inc.

 

On August 22, 2012, investment depositors, for whom the Company had previously recorded a deposit liability of $10.4 million contributed their outstanding net profits interests to the Company in exchange for common stock of Energy & Exploration Partners, Inc.

 

In July and August 2012, and by August 22, 2012, investment depositors, for whom the Company had previously recorded a deposit liability of $1.2 million, contributed their outstanding net profits interests to the Company in exchange for common stock. The Company also returned $1.7 million in cash to depositors, for whom it had previously recorded a deposit liability of $1.5 million, in exchange for a release of its obligation to provide returns under the Company’s letter agreements with them.

 

On August 22, 2012, the Company assigned its ownership interests in Energy & Exploration Partners Operating, LP, Energy & Exploration Partners Operating GP, LLC, North American Shale GP, LLC, North American Shale Investment Advisors, LLC, North American Shale Investment Fund GP, LP, and North American Shale Investment Fund, LP to Energy & Exploration Partners, LLC which rolled up to Energy & Exploration Partners, Inc.

 

On September 6, 2012, North American Shale GP, LLC, North American Shale Investment Advisors, LLC, North American Shale Investment Fund GP, LP, and North American Shale Investment Fund, LP, Indy Exploration I, LLC, Indy Exploration II, LLC and Indy Exploration III, LLC were merged into Energy & Exploration Partners, LLC, a subsidiary of the Company and subsequently dissolved.

 

Basis of Presentation

 

ENXP’s consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (“U.S. GAAP”). All significant intercompany transactions and account balances have been eliminated. As a company with less than $1.0 billion in revenue during its last fiscal year, the Company qualifies as an emerging growth company as defined in the recently enacted Jumpstart Our Business

 

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Startups Act of 2012, or the JOBS Act. An emerging growth company may take advantage of exemptions from various reporting requirements that are applicable to other public companies that are not an “emerging growth Company.”

 

As the membership interests of Energy & Exploration Partners, LLC, Energy & Exploration Partners Operating, LP and the controlling and non-controlling membership interests of NASIF were all entities under the common control of the majority owner of the Company, the contributions of these memberships and interests for shares of the Company’s common stock were not considered business combinations. Accordingly, the assets and liabilities contributed are presented in the consolidated financial statements on a basis reflecting their ownership by the Company as of the beginning of the earliest period presented, at their historical cost. In addition, certain investors in Energy & Exploration Partners, LLC’s activities in the Niobrara area contributed their investments, which were recorded as liability for investment deposits by Energy & Exploration Partners, LLC, to the Company for common stock. These investments were not considered to be a business by the Company and thus were not a business combination. Accordingly, the contribution was recorded at the amount Energy & Exploration Partners, LLC had historically recorded for the investment deposit liability. The assets and liabilities of Energy & Exploration Partners, LP which were each recorded at $0, were not contributed to the Company.

 

Reclassifications

 

Certain reclassifications have been made to the prior years’ financial statements to conform to the current year presentation. These reclassifications had no effect on previously reported results of operations, cash flows or retained earnings. These reclassifications include $11,000 related to production taxes formerly presented as lease operating expense and currently presented as production tax expense and $1.0 million related to loss on early extinguishment of debt formerly presented as interest expense and currently presented as loss on early extinguishment of debt, both reclassifications were on the consolidated statement of operations for the year ended December 31, 2012.

 

Accounting Estimates

 

The accompanying consolidated financial statements are prepared in conformity with U.S. GAAP, which requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates.

 

Significant assumptions are required in the quantification and valuation of proved oil and natural gas reserves, which as described herein may affect the amount at which oil and natural gas properties are recorded and related depreciation, depletion, amortization and impairment are calculated. Other significant estimates include but are not limited to asset retirement obligations, fair value of derivative financial instruments, fair value of equity-based compensation, and deferred tax assets and liabilities. The Company evaluates its estimates and assumptions on a regular basis. Changes in facts and circumstances or additional information may result in revised estimates, and actual results could differ from these estimates.

 

Cash and Cash Equivalents

 

Cash and cash equivalents include investments with original maturities of three months or less at the date of acquisition. The Company considers all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents. The Company determines the appropriate classification of its investments in cash and cash equivalents at the time of purchase and reevaluates such designation at each balance sheet date.

 

Debt Service Deposits

 

Debt service deposits consist of cash held on the Company’s behalf by its lenders for the purpose of servicing its debt requirements.

 

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In accordance with the Company’s previous agreement with Guggenheim Corporate Funding, LLC (the “Guggenheim Credit Facility”), the Company was required to direct all cash receipts from its credit parties directly to a Lockbox account and maintain a cash balance of an amount equal to the positive difference between $11.0 million minus 50% of the amounts paid by the Company in an equity account prior to termination of the Guggenheim Credit Facility in April 2013.

 

Revenue Recognition and Accounts Receivable

 

ENXP’s oil and natural gas are sold by the Company as the operator and its operating partners, for properties in which the Company has an interest, to various purchasers. The Company recognizes oil and natural gas revenues based on the quantities of its proportionate share of such production at market prices.

 

Accounts receivable are generated from the sale of oil and natural gas to various customers. The Company’s accounts receivable are uncollateralized and are generally due within 30 days of the invoice date. No interest is charged on past-due balances. Payments made on all accounts receivable are applied to the earliest unpaid items. Management periodically reviews accounts receivable. The allowance for doubtful accounts is established through provisions charged against income and is maintained at a level believed adequate by management to absorb estimated bad debts based on historical experience and current economic conditions. As of December 31, 2013 and 2012, the Company did not have any reserves for doubtful accounts, and did not incur any expenses related to bad debts in any period presented.

 

Unevaluated Oil and Natural Gas Properties

 

The Company acquires unevaluated leasehold interests in oil and natural gas leasehold acreage for the purpose of either exploiting them or selling them to third parties. All costs identifiable with acquisition of these leasehold interests are capitalized.

 

Unevaluated property acquisition costs primarily include leasehold costs paid to secure oil and natural gas mineral leases, but may also include broker and legal expenses, geological and geophysical expenses and capitalized internal costs associated with developing oil and natural gas prospects on these properties.

 

Costs associated with unevaluated properties are excluded from the full cost pool until the Company has made a determination as to the existence of proved reserves or until an evaluation that an impairment has occurred is made. The Company reviews its unevaluated properties at the end of each quarter to determine whether the costs incurred should be transferred to the full cost pool and thereby subject to amortization.

 

Full Cost Accounting

 

The Company utilizes the full-cost method of accounting for its investments in oil and natural gas properties. Under this method, all costs associated with the acquisition, exploration, development and abandonment of oil and natural gas properties and reserves, including unproved and unevaluated property costs, are capitalized as incurred and accumulated in a single cost center representing the Company’s activities, which are undertaken exclusively in the United States. Such costs include lease acquisition costs, geological and geophysical expenditures, lease rentals on undeveloped properties, costs of drilling both productive and non-productive wells, capitalized interest on qualifying projects and general and administrative expenses directly related to acquisition, exploration and development activities, but do not include any costs related to production, selling or general corporate administrative activities which are expensed as incurred.

 

Capitalized costs related to unproved properties will be retained as unevaluated properties until such time that such properties are evaluated and proved reserves may be assigned or until such time when the Company determines that impairment has occurred. The Company capitalizes interest, if debt is outstanding, on capital expenditures related to its unevaluated properties and wells in process of being drilled until such properties are

 

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ready for their intended use. When proved reserves are discovered, the related acquisition costs and drilling costs are transferred into the amortization base, whereby properties are amortized at the beginning of the quarter in which they are classified as proved. Additionally the Company includes the costs of drilling exploratory dry holes and the related leasehold costs in the amortization base immediately upon determination that such wells are non-commercial.

 

All capitalized costs of oil and natural gas properties included in the amortization base are amortized using the units-of-production method based on production estimates of total proved reserve quantities. In addition to costs associated with evaluated properties, the amortization base includes estimated future development costs to be incurred in developing proved reserves as well as estimated plugging and abandonment costs.

 

Under the full-cost method of accounting, the Company is required to periodically perform a ceiling test which determines a limit on the book value of its oil and natural gas properties. If the net capitalized cost of oil and natural gas properties including capitalized asset retirement costs, net of related deferred income taxes, exceeds (i) the present value of estimated future net revenues from proved reserves discounted at 10%, (ii) plus cost of unproved oil and natural gas properties not being amortized, (iii) plus the lower of cost or estimated fair value of unproved oil and natural gas properties included in the amortization base, net of related tax effects, the excess is charged to expense and reflected as additional accumulated depreciation, depletion, and amortization. Any such write-downs are not recoverable or reversible in future periods.

 

Other Property and Equipment

 

Other property and equipment are stated at cost less accumulated depreciation. Depreciation is calculated using the straight-line method over the estimated useful lives (ranging from 3 to 7 years) of the respective assets. The costs of normal maintenance and repairs are charged to expense as incurred unless they extend the useful life of the asset. Material expenditures that increase the life of an asset are capitalized and depreciated over the estimated remaining useful life of the asset. The cost of equipment sold, or otherwise disposed of, and the related accumulated depreciation are removed from the accounts and any gain or loss is reflected in current operations.

 

Currently, the Company owns land, certain computer software, hardware and other office-related equipment. Depreciation expense related to other property and equipment was $162,000 for each of the years ended December 31, 2013 and 2012, and $29,000 for the year ended December 31, 2011.

 

Oil and Natural Gas Reserve Quantities

 

The estimates of oil and natural gas reserves as of December 31, 2013 and 2012 are based on reports prepared by Cawley, Gillespie & Associates, Inc. (“CG&A”), independent reservoir engineers. The Company had no proved reserves as of December 31, 2011.

 

Estimates of proved reserves are based on the quantities of oil and natural gas that engineering and geological analyses demonstrate, with reasonable certainty, to be recoverable from established reservoirs in the future under current operating and economic parameters. CG&A prepares the reserve and economic evaluation of the Company’s properties, utilizing information provided to it by management and other information available, including information from the operator of the property.

 

Asset Retirement Obligations

 

The Company has obligations under its lease agreements and federal regulations to remove equipment and facilities from leased acreage and return such land to its original condition. In general, the Company’s future asset retirement obligations (“ARO”) relate to future costs associated with plugging and abandonment of its oil and natural gas wells, removal of equipment and facilities from leased acreage and returning such land to its

 

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original condition. The ARO is recorded as a liability at its estimated present value in the period in which it is incurred with a corresponding increase in the carrying amount of the related oil and gas property on the balance sheet. Periodic accretion of the discounted value of the estimated liability is recorded as an expense in the consolidated statement of operations. The amounts recognized are based on non-recurring level 3 fair value inputs, including future retirement costs, future well life, inflation factors and the credit-adjusted risk-free interest rate. Revisions to the liability can occur due to changes in its estimate or if federal or state regulators enact new plugging and abandonment requirements. At the time of actual plugging and abandonment of the Company’s oil and natural gas wells, any gains or losses associated with the operation in the amortization base to the extent that the actual costs are different from the estimated liability are included.

 

Derivatives and hedging

 

The Company’s risk management program is intended to reduce its exposure to commodity prices and to assist with stabilizing cash flows. Accordingly, the Company utilizes derivative financial instruments to manage its exposure to commodity price fluctuations. These transactions are primarily in the form of either swaps with fixed settlements or collars (calls and puts). ENXP has not designated any of its derivative instruments as hedges; therefore, the derivatives are carried at fair value on the consolidated balance sheets as assets or liabilities and all changes in fair value are recorded as gains and losses in the statements of operations. See Note 9—Derivative Financial Instruments for additional information related to derivative instruments.

 

Share-Based Compensation

 

The Company follows ASC 718, Compensation- Stock Compensation (“ASC 718”), which requires the measurement and recognition of compensation expense for all share-based payment awards, including restricted stock units, based on estimated grant date fair values. Restricted stock units are valued using the market price of our common shares on the date of grant. The Company records compensation expense, net of estimated forfeitures, over the requisite service period.

 

Income Taxes

 

Effective April 13, 2012, Energy & Exploration Partners, LLC terminated its election to report as an S Corporation and became a C Corporation for federal income tax reporting purposes. Subsequently, the Company accounts for income taxes using the asset and liability method. Deferred tax assets and liabilities arise from expected future tax consequences related to temporary differences between book carrying amounts and tax bases of assets and liabilities. Deferred tax assets and liabilities are measured using enacted tax rates anticipated being applied to taxable income in years in which temporary differences and carry forwards are expected to be recovered or settled. The effect on deferred tax assets and liabilities, specific to a change in tax rates, is recognized in income in the period that includes the enactment date. Valuation allowances are established when necessary to reduce the deferred tax asset to the amount more likely than not to be recovered.

 

Additionally, the Company is required to determine whether it is more likely than not (a likelihood of more than 50%) that a tax position will be sustained upon examination, including resolution of any related appeals or litigation processes, based on the technical merits of the position in order to record any financial statement benefit. If that step is satisfied, then the tax position to determine the amount of benefit to recognize in the financial statements is measured. The tax position is measured at the largest amount of benefit that has greater than a 50% likelihood of being realized upon ultimate settlement. Any interest or penalties would be recognized as a component of income tax expense.

 

The Company applies significant judgment in evaluating its tax positions and estimating its provision for income taxes. During the ordinary course of business, there are many transactions and calculations for which the ultimate tax determination is uncertain. The actual outcome of future tax consequences may differ significantly from these estimates, which could impact the Company’s financial position, results of operations and cash flows.

 

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The Company, does not have any uncertain tax positions and, as such, did not record a liability as of December 31, 2013, 2012 or 2011.

 

The tax years 2010 through 2012 remain open to examination by the federal and state taxing jurisdictions in which the Company operates.

 

Other Long-Term Assets

 

Other long-term assets consist primarily of deferred offering costs related to the Company’s planned initial public offering (“IPO”). Upon closing of the IPO, the proceeds of the offering, net of the offering costs, will be recorded as common stock at par value and additional paid-in capital. In any case where the IPO process is terminated, or where capitalized costs do not provide future value in the IPO process, the offering costs will be charged to expense.

 

Earnings per Share

 

The Company reports basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share, which includes the effect of all potentially dilutive securities, unless their impact is anti-dilutive.

 

Financial Instruments

 

The carrying amounts reported on the balance sheet for cash and cash equivalents, deposits, accounts receivable, prepaid expenses, accounts payable, accrued liabilities, royalties payable, advances from joint interest owners, dividends payable and other current liabilities approximate fair values, due to the short-term maturity of these instruments.

 

The carrying amounts of derivative instruments reported on the consolidated balance sheets are the estimated fair value of the Company’s derivative instruments. See Note 9—Derivative Financial Instruments for additional information related to the Company’s derivative instruments.

 

Credit and Market Risk

 

The Company is exposed to counterparty risk from the purchasers of its oil and natural gas, its operating partners, its derivative counterparties and its joint venture partners. Oil and natural gas and joint interest receivables are generally unsecured. During 2013 the Company started operating a portion of its properties, and approximately 73% of revenues and 72% of accounts receivable were from one purchaser: Shell Trading Company (US). Additionally, one operator Halcón Resources with 14.6% of the Company’s accounts receivables balance as of December 31, 2013 accounted for more than 10% of the accounts receivables balance. The inability or failure of the Company’s significant purchasers, derivative counterparties, or partners to meet their obligations or their insolvency or liquidation may adversely affect the Company’s financial results.

 

During 2012 and 2013, the Company had cash deposits in certain banks that at times exceeded the maximum insured by the Federal Deposit Insurance Corporation. The Company monitors the financial condition of the banks and has experienced no losses on these accounts.

 

Environmental Expenditures

 

The Company is subject to extensive federal, state and local environmental laws and regulations. These laws regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Liabilities for expenditures of a non-capital nature are recorded when environmental

 

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assessment and/or remediation is probable, and the costs can be reasonably estimated. Such liabilities are generally not discounted unless the timing of cash payments for the liability or component is fixed or reliably determinable.

 

Liabilities for loss contingencies, including environmental remediation costs arising from claims, assessments, litigation, fines, and penalties and other sources, are recorded when it is probable that a liability has been incurred and the amount of the assessment and/or remediation can be reasonably estimated. Recoveries of environmental remediation costs from third parties, which are probable of realization, are separately recorded and are not offset against the related environmental liability.

 

The Company believes it is in compliance with all applicable federal, state and local regulations associated with its properties. Accordingly, no environmental remediation liability or loss associated with the Company’s properties was recorded as of December 31, 2013 and 2012.

 

Recent Accounting Developments

 

In February 2013, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2013-04, Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date, which requires an entity that is joint and severally liable to measure the obligation as the sum of the amount the entity has agreed with co-obligors to pay and any additional amount it expects to pay on behalf of one or more co-obligors. Required disclosures include a description of the nature of the arrangement, how the liability arose, the relationship with co-obligors and the terms and conditions of the arrangement. The effective date for the amendment is for annual periods beginning after December 15, 2013, and interim periods within those annual periods. The amendment is to be applied retrospectively to all prior periods presented. The Company does not expect its disclosures to be affected by ASU 2013-04.

 

In July 2013, the FASB issued ASU 2013-11, Income Taxes (Topic 740); Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a similar Tax Loss, or a Tax Credit Carryforward Exists - a consensus of the FASB Emerging Task Force, which provided guidance on the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. This guidance requires an entity to present an unrecognized tax benefit as a liability in the financial statements if (i) a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position, or (ii) the tax law of the applicable jurisdiction does not require the entity to use, and the entity does not intend to use, the deferred tax asset to settle any additional income taxes that would result from the disallowance of a tax position. Otherwise, an unrecognized tax benefit is required to be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward. Previously, there was diversity in practice as no explicit guidance existed. The amendment is effective for annual periods and interim periods beginning after December 15, 2013 and is to be applied prospectively. The Company does not expect its balance sheet presentation or its disclosures to be affected by ASU 2013-11.

 

Recently Adopted Accounting Standards

 

In December 2011 the FASB issued ASU No. 2011-11, Balance Sheet (Topic 210), Disclosures about Offsetting Assets and Liabilities (“ASU 2011-11”). ASU 2011-11 required entities to disclose both gross information and net information about both instruments and transactions eligible for offset in the statement of financial position and instruments and transactions subject to an agreement similar to a master netting arrangement. In January 2013, an update was issued to further clarify that the disclosure requirements are limited to derivatives, repurchase agreements, and securities lending transactions to the extent that they are (i) offset in the financial statements or (ii) subject to an enforceable master netting arrangement or similar agreement.

 

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Adoption of the new guidance, effective for the fiscal year beginning January 1, 2013, had no impact on the Company’s consolidated financial position, results of operations or cash flows. However, we were required to include additional disclosures relating to our derivative instruments. See Note 9—Derivative Financial Instruments for further discussion on the Company’s derivative instruments.

 

3. Oil and natural gas properties and equipment

 

The following table presents a summary of the Company’s oil and natural gas properties and related accumulated depletion and impairment as of December 31, 2013 and 2012 (in thousands):

 

     December 31,  
     2012     2013  

Subject to depletion

   $ 6,059      $ 158,955   
  

 

 

   

 

 

 

Not subject to depletion:

    

Exploration and extension wells in progress

     5,595        404   

Other capital costs:

    

Incurred in 2013

     0        66,808   

Incurred in 2012

     3,972        3,972   

Incurred in 2011

     18,866        15,204   

Incurred in 2010 and prior

     2,742        2,698   
  

 

 

   

 

 

 

Total not subject to depletion

     31,175        89,086   
  

 

 

   

 

 

 

Gross oil and natural gas properties

     37,234        248,041   

Less accumulated depletion and impairment(1)

     (4,264     (19,368
  

 

 

   

 

 

 

Net oil and natural gas properties

   $ 32,970      $ 228,673   
  

 

 

   

 

 

 

 

(1)   Accumulated depletion, depreciation and amortization as of December 31, 2013 and 2012 include full cost ceiling impairment expense of approximately $12.4 million and $4.0 million, respectively.

 

Investments in unevaluated oil and natural gas properties and exploration and development projects for which depletion expense is not currently recognized, and for which exploration or development activities are in progress, qualify for interest capitalization. The capitalized interest is determined by multiplying the Company’s weighted-average borrowing cost on debt by the average amount of qualifying costs incurred that are excluded from the full cost pool; however, the amount of capitalized interest cannot exceed the amount of gross interest expense incurred in any given period. The capitalized interest amounts are recorded as additions to unevaluated oil and natural gas properties on the consolidated balance sheets. As the costs excluded are transferred to the full cost pool, the associated capitalized interest is also transferred to the full cost pool. For the years ended December 31, 2013 and 2012, the Company capitalized interest costs of $3.8 million and $0.2 million, respectively.

 

The Company capitalizes certain general and administrative costs related to individuals directly involved in the Company’s acquisition, exploration and development activities based on the percentage of their time devoted to such activities. These costs include salaries and related benefits. For the years ended December 31, 2013 and 2012, the Company capitalized general and administrative costs of $3.6 million and $2.1 million, respectively.

 

Impairment and Abandonment of Unevaluated Properties

 

ENXP’s unproved and unevaluated properties are assessed at a minimum on an annual basis on an individual prospect level for possible impairment based upon changes in operating or economic conditions.

 

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Unproved and unevaluated properties are nonproducing and do not have estimable cash flow streams. Therefore, the Company estimates the fair value of these properties by obtaining, when available, information about recent market transactions in the vicinity of the prospects and adjusts the market data as needed to give consideration to the proximity of the prospects to known fields and reservoirs, the extent of geological and geophysical data on the prospects, the assignment of proved reserves, intent to drill, remaining lease terms, recent drilling results in the vicinity of the prospects, and other risk-related factors such as drilling and completion costs, estimated product prices and other economic factors. Based on these assessments, the Company includes the cost of such properties whose carrying value exceeds its estimated value with other evaluated properties to be amortized and subject to the full-cost ceiling impairment of oil and natural gas properties. The Company categorizes the measurement of fair value of unproved properties as level 3 non-recurring measurements.

 

During the year ended December 31, 2013, the Company transferred $18.5 million of unevaluated property costs to the full cost pool related to impaired value, primarily due to a decline in fair value of certain leases related to the remaining lease terms. For the year ended December 31, 2012, the Company recognized no impairment on unevaluated properties.

 

During the year 2011, the Company’s business focus was primarily in the purchase and sale of leases and the Company owned no oil and gas assets with proved reserves. As a result, all costs associated with the impairment and abandonment on such leases was charged to impairment expense on the consolidated statement of operations. The Company recorded an impairment expense of $679,000 related to abandoned leaseholds during the year ended December 31, 2011.

 

Full-Cost Ceiling Impairment of Oil and Natural Gas Properties

 

Under the full cost method of accounting for oil and natural gas properties, net capitalized costs of oil and natural gas properties are limited to the lower of unamortized costs less related deferred income taxes or the cost ceiling, with any excess above the cost center ceiling charged to operations as a full-cost ceiling impairment. Properties included in the total net capitalized costs include, but are not limited to, proved properties, unproved evaluated properties and unevaluated properties deemed to have been impaired.

 

ENXP’s net capitalized costs at March 31, 2013 and December 31, 2012 exceeded the ceiling amount. As a result, the Company recorded a full cost ceiling test impairment of $8.4 million and $4.0 million for the years ended December 31, 2013 and 2012, respectively.

 

4. Significant Purchases and Sales of Assets

 

During the years 2013 and 2012, ENXP acquired and sold leases and leasehold interest. Below is a description of the Company’s purchase and sales activities for the years ended December 31, 2013 and 2012.

 

2013 Acquisitions

 

On April 8, 2013, ENXP closed on its purchase and sale agreement with Chesapeake Energy Corporation, (“Chesapeake”) and acquired generally a 100% operated working interest in Chesapeake’s acreage in the Eaglebine for approximately $93.0 million (the “Chesapeake Acquisition”), consisting of approximately $75.0 million in cash and a subordinated promissory note in the principal amount of $18.0 million with Chesapeake. See Note 6—Note Payable for additional discussion on the $18.0 million subordinated unsecured note with Chesapeake. The acquired properties consisted primarily of leasehold acreage, and included nine producing wells, one well awaiting a pipeline connection and one non-producing well. Of the $93.0 million purchase price, $6.9 million represented evaluated properties and the remaining $86.1 million represented unevaluated properties.

 

In connection with the Chesapeake Acquisition, ENXP executed an Assignment of Contracts and Assumption Agreement with Energia Tejas, LLC (“Energia”). In accordance with the agreement, for a purchase

 

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price of $0.9 million the Company acquired Energia’s interests in oil and gas leases, excluding their overriding royalty interests, in the AMI created by the AMI, Participation, and Lease Purchase Agreement dated June 1, 2010 between Chesapeake and Energia.

 

2012 Acquisitions

 

On April 5, 2012, ENXP entered into a purchase and sale agreement with a Texas exploration and production company to purchase a series of undeveloped leasehold acreage in Grimes County, Texas. The gross purchase price of this transaction was $5.3 million.

 

On April 10, 2012, EX Operating LLC, executed a lease purchase agreement to purchase certain oil and gas leases in Lynn County, Texas and delivered a deposit of $1.0 million. On May 15, 2012, EX Operating LLC then assigned all of its rights, title and interest in and to the lease purchase agreement to Energy & Exploration Partners, LLC for $1.0 million, and Energy & Exploration Partners, LLC purchased the leases effective as of April 10, 2012 for $1.9 million.

 

On July 24, 2012, the Company acquired a series of undeveloped leasehold acreage in Walker County, Texas. The gross purchase price of this transaction was approximately $2.0 million.

 

On September 10, 2012, ENXP entered into a purchase and sale agreement with Chesapeake pursuant to which ENXP agreed to purchase 100% of Chesapeake’s acreage in the Eaglebine. The agreement initially provided for a closing date of October 31, 2012. The Company exercised its right to extend the closing date of the sale to February 14, 2013 by paying $3.5 million, $3.0 million and $3.5 million on September 10, 2012, October 30, 2012, and January 2, 2013 respectively. On April 8, 2013, the sale was closed and the Company acquired a 100% operated working interest in Chesapeake’s acreage in the Eaglebine in exchange for approximately $93.0 million.

 

On September 25, 2012, ENXP acquired undeveloped leasehold acreage in Madison County, Texas. The gross purchase price of this transaction was approximately $2.3 million.

 

Sales and Conveyances

 

Net gains on sales of assets for the years ended December 31, 2013 and 2012 are as follows (in thousands):

 

     Year ended December 31,  
     2011      2012      2013  

Gain on sale of assets

   $ 573       $ 34,738       $ 14,275   

 

2013 Sales and Conveyances

 

Pursuant to the Company’s agreement with Halcón Resources, Inc. (“Halcón”), working interests conveyed to Halcón were subject to a contingent payment of $1,000 per net acre conveyed, subject to the commerciality of one or two wells drilled and completed within the area of mutual interest created pursuant to the agreement (“AMI #1”). See 2012 Sales and Conveyances below for further discussion on this transaction. During the year ended December 31, 2013, one of the wells became commercial and Halcón elected to pay one-half of the contingent payment, or $14.6 million to the Company. The Company follows the full cost method of accounting for its oil and gas properties. Generally, under this method, sales are accounted for as adjustments to capital costs, with no gains or losses realized unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves to such cost center. As this contingent payment is part of a previous sale which significantly altered the relationship between the basis in the Company’s properties in AMI#1 and the Company’s de minims proved reserves at the time of sale, the proceeds of $14.6 million net of $0.4 million in fees associated with the receipt of the proceeds is shown as a gain on the statement of operations at December 31, 2013. Additionally, on March 31, 2014, Halcón elected to pay the remaining $14.6 million of the contingent

 

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payment by May 15, 2014. If Halcón does not pay the remaining $14.6 million by May 15, 2014, the Company can require Halcón to reconvey to us, for no additional consideration, all of the interests in the acreage it acquired pursuant to the purchase and sale agreement and the wells drilled under the AMI #1 agreement or pursue other remedies. The $14.6 million contingent payment will be considered additional proceeds and recorded as a gain on the statement of operations during March 2014.

 

On June 25, 2013, the Company sold its 100% interest in its evaluated and unevaluated Niobrara assets located in Weld County, Colorado for consideration of $5.5 million, subject to customary purchase price adjustments. ENXP did not recognize any gain or loss on this sale as the Company follows the full cost method of accounting for its evaluated oil and gas properties. Generally under this method, gains or losses are not realized for the sale or abandonment of evaluated properties but are however, accounted for as adjustments of capitalized costs unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas attributable to such cost center.

 

2012 Sales and Conveyances

 

The Company, as sellers, closed on multiple property conveyances with a third-party operator, Halcón Resources, Inc. (“Halcón”), to develop the Company’s undeveloped leasehold acreage in the prospect area principally focused on the Eaglebine formation. The proceeds of these transactions were approximately $45.4 million for a sale of a 65% working interest in the undeveloped leasehold acreage in an area collectively known as Area of Mutual Interest #1 (“AMI #1”) and an 80% working interest in the undeveloped leasehold acreage in an area collectively known as Area of Mutual Interest #2 (“AMI #2”).

 

On August 23, 2012, the Company entered into a purchase and sale agreement with CEU Huntsville, LLC, (“Huntsville”), a subsidiary of Exelon Generation Company, LLC, to sell a 10% non-operated working interest in its Eaglebine acreage in AMI #1 and a 5% non-operated working interest in AMI #2. Pursuant to the first closing of this agreement, the Company conveyed acreage in AMI #1 for $24.7 million and received an additional $0.8 million as reimbursement for the buyer’s 10% share of a well. The agreement provides for future closings of additional acreage. Following the final closings with both Halcón and Huntsville, the Company retained a 25% working interest in AMI #1 and a 15% working interest in AMI #2. For future acquisitions, Huntsville can elect to participate in AMI #1 or AMI #2 by paying its pro-rata 10% share of all acreage costs in AMI #1 and its pro-rata 5% share of all acreage costs plus $100 per net mineral acre in AMI #2. In addition to the cash proceeds received from both closings, if the buyer achieves a specified rate of return, it will re-convey 30% of the working interests it holds in wells and acreage in both AMI #1 and AMI #2 back to the Company. On August 24, 2012, ENXP made a payment of $5.0 million, or 20% of the proceeds, net of broker fee, from this sale, to its lender to be applied against its outstanding principal balance, pursuant to provisions of its Guggenheim Credit Facility. On September 28, 2012 ENXP made an additional conveyance under this agreement for $7.9 million and on October 5, 2012, a payment of $1.5 million from this sale was made to the Company’s lender to be applied against its outstanding principal balance, pursuant to provisions of the Guggenheim Credit Facility.

 

In December 2012, the Company conveyed additional working interests in newly acquired undeveloped leasehold acreage in AMI #2. Funding by Huntsville for gross proceeds of $1.5 million was received by the Company on January 16, 2013, of which $0.6 million related to acquired interests and $0.9 million related to reimbursements of costs.

 

5. Asset Retirement Obligations

 

The Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred and if a reasonable estimate of fair value can be made. The asset retirement obligation is capitalized as part of the carrying amount of the long-lived asset. The Company determines its asset retirement obligations on its oil and natural gas properties by calculating the present value of estimated cash flows related to the estimated liability. The fair value of the liability is measured on a non-recurring basis using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging,

 

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abandonment and remediation costs, inflation rate and well life. The inputs are calculated based on historical data as well as current estimated costs. See Note 10—Fair Value Measures for additional discussion.

 

The following table summarizes the changes in our ARO for the year ended December 31, 2013 and December 31, 2012 (in thousands).

 

     December 31,  
     2012      2013  

Liability for asset retirement obligation, beginning of year

   $ —         $ 16   

Obligations for wells acquired and wells drilled

     16         338   

Change in estimates

     —           840   

Accretion expense

     —           98   
  

 

 

    

 

 

 

Liability for asset retirement obligation, end of year

     16         1,292   

Less: current asset retirement obligation

     —           (655
  

 

 

    

 

 

 

Long-term asset retirement obligation

   $ 16       $ 637   
  

 

 

    

 

 

 

 

6. Notes Payable

 

The following table summarizes our debt as of December 31, 2013 and 2012 (in thousands):

 

     December 31,  
     2012      2013(4)  

Guggenheim Credit Facility

   $ 21,293       $ —     

Senior Unsecured Note—Tranche A(1)

     —           124,731   

Senior Unsecured Note—Tranche B(2)

     —           24,263   

Subordinated Unsecured Note—Chesapeake(3)

     —           19,342   
  

 

 

    

 

 

 

Total debt

   $ 21,293       $ 168,336   

Less current portion

     7,102         —     
  

 

 

    

 

 

 

Total long-term debt

     14,191         168,336   
  

 

 

    

 

 

 

 

(1)   Amount is net of unamortized discount of $15.3 million at December 31, 2013. See “Senior Unsecured Notes” below for more details.
(2)   Amount is net of unamortized discount of $0.8 million at December 31, 2013. See “Senior Unsecured Notes” below for more details.
(3)   Amount includes paid in kind interest of $1.3 million at December 31, 2013. See “Subordinated Unsecured Note” below for more details.
(4)   See Note 13 Commitments and Contingencies for a five year maturity schedule.

 

Guggenheim Credit Facility

 

On June 26, 2012, ENXP entered into a $100.0 million Senior Secured Advancing Line of Credit with an initial borrowing base of $30.0 million, with Guggenheim Corporate Funding, LLC (“Guggenheim”), which is referred to as the Guggenheim Credit Facility.

 

The Guggenheim Credit Facility bore interest at a variable rate published by the Wall Street Journal calculated as the Prime Rate (“Prime Rate”) plus 10.0%, with a Prime Rate floor of 5.0%.

 

The Guggenheim Credit Facility provided for a 5.0% Overriding Royalty Interest (“ORRI”) grant to Guggenheim, proportionally reduced to the Company’s working interest, which applied to substantially all production from the Eaglebine acreage owned during the existence of such credit facility. This ORRI was

 

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reduced to 0.5%, proportionally reduced to the Company’s working interest of total production, after Guggenheim achieved an internal rate of return of 32.5% for at least one year. The ORRI would have been earned in increments of one twelfth (1/12) times the number of wells funded by the Guggenheim Credit Facility up to twelve wells.

 

The Guggenheim Credit Facility required cash to be maintained on deposit to fund future drilling costs in bank accounts controlled by the Company’s lenders. The $4.2 million recorded in debt service deposits at December 31, 2012 represented funds controlled by this lender.

 

On April 8, 2013, ENXP repaid the $17.3 million net outstanding balance on the Guggenheim Credit Facility and terminated the lending facility. The Company recognized a loss associated with the debt pay off of $3.7 million during the year ended December 31, 2013, consisting of a make-whole payment made to retire the credit facility and the elimination of unamortized debt issuance costs related to this note. The loss is included in the consolidated statement of operations under the caption “Loss on early extinguishment of debt.”

 

Senior Unsecured Note

 

Tranche A Notes

 

On April 8, 2013, ENXP issued $140.0 million of senior unsecured tranche A notes with an original issue discount of 3%, or $4.2 million, to affiliates of Highbridge Principal Strategies, LLC, (“Highbridge”), and affiliates of Apollo Investment Corporation, (“Apollo”). These notes mature on April 8, 2018. The Company used a portion of the net proceeds of the Tranche A notes to repay indebtedness under its previously existing credit facility with Guggenheim and fund the Chesapeake Acquisition. In addition to the Tranche A notes, Highbridge and Apollo issued to the Company, a commitment letter for a $75.0 million Senior Secured Term Loan (the “Term Loan”), with funding subject to satisfaction of certain other conditions.

 

From April 8, 2013 through April 7, 2017, the Tranche A notes bear interest at a rate equal to the greater of (i) 15% per year and (ii) the annual rate payable on the Term Loan once funded plus 2%. If the Company does not refinance the Tranche A notes by April 8, 2017, the interest rate from April 8, 2017 until maturity will be the greater of (i) 20% per year and (ii) the annual rate payable on the Term Loan plus 2% interest is due quarterly.

 

Tranche B Notes

 

On December 12, 2013, ENXP entered into the first supplement to its senior unsecured notes agreement and issued $25.0 million of senior unsecured tranche B notes with an original issue discount of 3%, or $0.8 million, to Highbridge and Apollo. These notes mature on December 12, 2018.

 

From December 12, 2013 through December 11, 2017, the Tranche B notes bear interest at a rate equal to the greater of (i) 15% per year and (ii) the annual rate payable on the Term Loan once funded plus 2%. If the Company does not refinanced the Tranche B notes by December 12, 2017, the interest rate from December 12, 2017 until maturity will be the greater of (i) 20% per year and (ii) the annual rate payable on the Term Loan plus 2% interest is due quarterly.

 

The Company’s senior unsecured notes are subject to prepayment penalties if repaid within three years of issuance. For any prepayments made on or prior to October 8, 2015, the Company must pay a make-whole amount equal to the present value of the interest payable on the principal balance of the prepaid notes from the date of prepayment through October 8, 2015, discounted at a rate equal to the yield to maturity for the applicable United States treasury securities plus 50 basis points. For any prepayments made on or before April 8, 2016, the Company must pay a prepayment premium equal to 3% of the principal amount repaid.

 

The Company’s senior notes are unsecured and are guaranteed by all of its subsidiaries.

 

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The note purchase agreement related to the senior unsecured notes contains certain covenants that, among other things:

 

   

limit the Company’s investments, loans and advances and the payment of dividends and other restricted payments;

 

   

limit the Company’s incurrence of additional indebtedness, other than the Term Loan or, in the event the Term Loan is not approved, a $125.0 million reserve based loan;

 

   

prohibit the granting of liens, other than certain permitted liens;

 

   

prohibit mergers, consolidations and sales of all or a substantial part of our business or properties without lender consent;

 

   

limit general and administrative costs;

 

   

limit the Company’s capital expenditures to those allowed under the approved plan of development, (“APOD”), which must be submitted for approval no less than once yearly;

 

   

limit the Company’s acquisitions of oil and gas properties;

 

   

require the Company to meet certain financial tests consisting of an interest coverage ratio, minimum production volumes, PDP asset coverage ratio, proved reserves asset coverage ratio, total leverage ratio and current ratio beginning with the fiscal quarter ending December 2013 and calculated at the end of each subsequent quarter or semi-annually, as applicable; and

 

   

require minimum liquidity.

 

Additionally, the note purchase agreement related to the senior unsecured notes requires the Company to enter into commodity derivative contracts with respect to the following minimum percentages of anticipated production from proved developed producing reserves for a period of three years:

 

   

after three operated wells have been completed and producing for 60 days, 40%;

 

   

after five operated wells have been completed and producing for 60 days, 50%; and

 

   

after ten operated wells have been completed and producing for 60 days, 60%.

 

The Company generally may not enter into commodity derivative contracts with respect to more than 80% of anticipated production from proved developed producing reserves. All such commodity derivative agreements must be on terms approved by Highbridge.

 

The note purchase agreement related to the senior unsecured notes includes certain events of default, some of which may be outside of the Company’s control. The events of default include:

 

   

failure to pay any principal or interest due under the Term Loan;

 

   

failure to perform or otherwise comply with the covenants in the Term Loan;

 

   

bankruptcy or insolvency events involving us or our subsidiaries;

 

   

the entry of a judgment, order, decree, or arbitration award of more than $2.5 million individually or in the aggregate;

 

   

a change of control; or

 

   

failure to operate the Company’s oil & gas properties in a prudent manner.

 

The Company obtained a waiver from the holders of the senior unsecured notes in December 2013 that waived the application of the current ratio financial covenant for the period ending December 31, 2013 and any deviations from the APOD. At December 31, 2013, the Company was not in compliance with the interest coverage, minimum production, total leverage and minimum liquidity financial covenants under the senior unsecured notes. The Company obtained a waiver in March of 2014 that waived the Company’s failure to

 

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comply with the four financial covenants for the period ending December 31, 2013. Additionally, the lenders waived the application of the interest coverage, minimum production, total leverage and minimum liquidity financial covenants for the period ending March 31, 2014. The Company believes it is probable it will be in compliance with its debt covenants for the remainder of 2014. The Company’s plan is dependent upon proceeds from a capital raise, asset divestitures, or a combination of these transactions.

 

In connection with the issuance of the Tranche A notes, the Company issued to Highbridge and Apollo warrants to purchase an aggregate of 269,231 shares of its mandatory convertible preferred stock at an exercise price of $0.01 per share. To objectively determine the fair market value of these warrants, ENXP engaged a third-party valuation specialist to determine the fair market value of the series A and B preferred stock on the issue date of April 8, 2013. Based on the Probability-Weighted Expected Return (“PWERM”) approach, the fair value of our series A and B preferred stock, on a minority, non-marketable basis, as of April 8, 2013 was determined to be $51.12 per share resulting in a fair value of $13.8 million for the warrants issued. This amount was recorded as a discount to the value of the notes. The fair value on these warrants were measured at a fair value on a non-recurring basis using level 3 inputs. Each share of the preferred stock is convertible at the option of the holder prior to the Company’s initial public offering and will convert automatically upon completion of the initial public offering into 269,231 shares of the Company’s common stock. To the extent not previously exercised, at the completion of the initial public offering, the warrants will automatically be exercised on a net basis for the number shares of the Company’s common stock calculated as the shares of preferred stock issuable upon exercise of the warrants that would have been converted less a number of shares equal to the aggregate exercise price divided by the initial public offering price per share.

 

See Note 15. Subsequent Events for additional information regarding notes issued subsequent to December 31, 2013.

 

Term Loan

 

In August 2013, ENXP entered into an agreement with Highbridge and Apollo for a $75 million Term Loan. As of December 31, 2013 this agreement was still subject to approval from the limited partner’s advisory committee of Highbridge. Once the agreement is approved, ENXP may draw under the Term Loan in three installments of $25.0 million, subject to the satisfaction of certain conditions, including the Company’s achievement of the following rates of production:

 

   

For the first draw of $25.0 million, 30-day average production of 750 Boe/d, provided that no more than 44% of such production may be from a single well;

 

   

For the second draw of $25.0 million, 30-day average production of 1,250 Boe/d, provided that no more than 33% of such production may be from a single well;

 

   

For the final draw of $25.0 million, 30-day average production of 1,500 Boe/d, provided that no more than 25% of such production may be from a single well; and

 

   

Compliance with a proved developed producing reserve asset coverage ratio.

 

   

Final credit approval of the lenders

 

Although the Company has satisfied the production and reserve requirements to draw the full $75.0 million under the term loan, the Company has not received final credit approval of the lenders.

 

Each draw on the Term Loan is subject to an upfront fee payable to our lenders of 2% of the principal amount drawn.

 

Interest on the Term Loan will accrue at a floating rate of 3-month LIBOR plus 10%, with a LIBOR floor of 2%, payable quarterly.

 

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The Term Loan is secured by a first-priority security interest in substantially all of ENXP and its subsidiaries’ real and personal assets. All of ENXP’s subsidiaries will guaranty the Term Loan.

 

The Term Loan matures August 20, 2016 and is subject to prepayment penalties if repaid within two years of the initial funding date. For any prepayments made prior to 18 months following the initial funding date, ENXP must pay a make-whole amount equal to the present value of the interest payable on the principal balance of the prepaid amount from the date of prepayment through 18 months after the initial funding date, discounted at a rate equal to the yield to maturity for the United States treasury securities plus 50 basis points. For any prepayments made from 19 months through 24 months after the initial funding date, ENXP must pay a prepayment premium equal to the greater of (i) 3% of the principal amount prepaid and (ii) the amount necessary to return 1.25x the repaid principal amount.

 

The Term Loan agreement contains performance and financial covenants similar to those set forth in the note purchase agreement governing the Company’s senior unsecured notes. The Term Loan agreement also contains certain additional covenants that, among other things:

 

   

limit the Company’s incurrence of additional indebtedness (no provision made for a reserve based loan);

 

   

require the Company to meet a secured debt ratio, in addition to the various financial tests required under the senior unsecured notes; and

 

   

require the Company to achieve and maintain certain minimum production levels.

 

The Company obtained a waiver from the lenders under the Term Loan in December of 2013 that waived the application of the current ratio financial covenant for the period ending December 31, 2013 and any deviations from the APOD. At December 31, 2013, the Company was not in compliance with the interest coverage, minimum production, total leverage and minimum liquidity financial covenants under the Term Loan. The Company obtained a waiver in March of 2014 that waived the Company’s failure to comply with the four financial covenants for the period ending December 31, 2013. Additionally, the lenders waived the application of the interest coverage, minimum production, total leverage and minimum liquidity financial covenants for the period ending March 31, 2014. The Company believes it is probable it will be in compliance with its debt covenants for the remainder of 2014. The Company’s plan is dependent upon proceeds from a capital raise, asset divestitures, or a combination of these transactions.

 

As of December 31, 2013, the Company had not drawn any amounts on the Term Loan.

 

Subordinated Unsecured Note—Chesapeake Note

 

In connection with the Chesapeake Acquisition during April 2013, ENXP issued an $18.0 million subordinated unsecured note to Chesapeake. The Chesapeake note matures on the earlier of (i) October 8, 2018, (ii) the closing of the Company’s initial public offering or (iii) six months after the date of repayment of the Company’s senior debt (as defined in the Chesapeake note) in full. The Chesapeake note bears interest at 10% per annum until the senior debt (as defined in the Chesapeake note) is paid in full and 15% thereafter. Until the senior debt (as defined in the Chesapeake note) is paid in full, all interest shall be paid in kind (“PIK”), with any such PIK interest being added to the principal balance of this note at the end of each quarter. The principal balance of this note plus all accrued and unpaid interest is expected to be paid within three business days after the maturity date. At December 31, 2013, including PIK interest, $19.3 million was payable on the Chesapeake note.

 

Debt Issuance Costs

 

ENXP capitalizes certain direct costs associated with the issuance of long-term debt and amortizes to interest expense using the effective interest method such costs over the lives of the respective debt. During 2013, the Company capitalized approximately $2.0 million in costs associated with the issuance of its outstanding debt and expensed $179,000 of debt issuance costs. At December 31, 2013 and 2012, the Company had approximately $1.8

 

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million and $1.0 million, respectively, of debt issuance costs remaining that are being amortized over the lives of the respective debts.

 

7. Equity

 

During 2011, the sole equity owner of the Company coupled with investors in NASIF contributed $0.4 and $10.6 million to the Company, respectively. On June 25, 2012, the Company distributed $150,000 to its then sole equity owner. From July 25, 2012 to September 6, 2012, the Company effected its plan of reorganization, in which all membership and other interests were contributed to the Company for shares of its stock. On September 4, 2012 the Company’s sole director contributed 22,500 shares to the Company, to be used in the Company’s stock incentive plan. See Corporate Reorganization in Note 2—Summary of Significant Accounting Policies for additional discussion.

 

During 2012, the Company’s sole director approved the ENXP 2012 Stock Incentive Plan (“the Plan”). Awards were issued under the plan during 2012 and 2013. See Note 8—Share-Based Compensation below for further discussion.

 

8. Share Based Compensation

 

On August 22, 2012, the Company’s sole director approved the ENXP 2012 Stock Incentive Plan (“the Plan”). The Plan enables the Board of Directors to award incentive and non-qualified stock options, restricted stock, unrestricted stock and restricted stock units to the Company’s officers, employees, directors, consultants, and key persons, including prospective employees conditioned on their employment. The maximum number of shares that may be issued under the Plan is 225,000, and as of December 31, 2013, 86,970 shares were available for future grants and 12,500 shares were forfeited. The forfeiture was triggered by the departure of employees prior to vesting.

 

The vesting dates of certain awards issued under the plan were modified on November 16, 2012 and December 1, 2013. The modification included changes to vesting dates and the percentage of shares vesting at each vesting date.

 

The following table summarizes the number of share awards and vesting dates post modification for restricted shares granted:

 

    Tranche 1   Tranche 2   Tranche 3   Tranche 4   Tranche 5

Shares awarded

  50,000   65,000   12,821   5,130   5,079

First Vesting Date

  March 31, 2014   September 1, 2014   May 1, 2014   September 30, 2014   July 25, 2014

Second Vesting Date

  —     —     May 1, 2015   September 30, 2015   July 25, 2015

Third Vesting Date

  —     —     May 1, 2016   September 30, 2016   July 25, 2016

 

Compensation recognized for grants vesting under the Plan was $9.7 million and $3.9 million for the years ended December 31, 2013 and 2012, respectively. During the year ended December 31, 2013, $9.1 million of the recognized compensation was recorded as share-based compensation and included in “General and administrative expenses” in the consolidated statement of operations and $0.6 million of the recognized compensation was recorded a capitalized internal costs and initially included in “Unevaluated oil and natural gas properties” on the consolidated balance sheet. Once unevaluated properties are evaluated all related unevaluated property costs, including capitalized share-based compensation, are transferred into “Evaluated oil and natural gas properties” to be amortized.

 

Total unrecognized compensation expense related to unvested options expected to be recognized over the remaining weighted vesting period of 1 year was $1.8 million at December 31, 2013.

 

To objectively determine the share price, the Company engaged a third-party valuation specialist to determine the fair market value of its common stock at the respective grant dates. In performing the valuation analysis, the valuation specialist utilized the Company’s audited financial statements for the years 2010 through 2012, unaudited financial statements for the six month interim period ending June 30, 2012, the one month period ended January 31, 2013, the five months period ended May 31, 2013, and the nine months ended

 

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September 30, 2013 selected unaudited financial statement data as of the valuation date, financial forecasts for the periods 2012 thru 2018, executed purchase and sale agreements that occurred during the period, the Company’s Form S-1 Registration Statement filed on September 10, 2012 through November 15, 2013 as well as other ancillary documents and schedules related to the Company.

 

In addition, the valuation specialist discussed the nature and history of ENXP, including historical operating and financial results and future earning capacity. Management took into consideration an analysis of historical and forecasted financial statements and other financial and operational data concerning ENXP, an analysis of company activities, assets, economic conditions and general trends relating to the oil and gas exploration and development industry and performed research and analysis concerning the value of the Company’s assets based on a market approach estimate of undeveloped acreage leasing costs of comparable properties observed in third party transactions. Management reviewed and approved the assessment of the valuation specialist.

 

A summary of the status of our non-vested shares issued under the Plan and the change during the year ended December 31, 2013 is presented below (in thousands):

 

     Number of
Shares
    Weighted
Average
Grant-Date
Fair Value
 

Non-vested at December 31, 2011

     —        $ —     

Granted

     125,000        127.00   

Vested

     —          —     

Cancelled

     —          —     

Forfeited

     —          —     
  

 

 

   

 

 

 

Non-vested at December 31, 2012

     125,000        127.00   

Granted

     25,530        41.54   

Vested

     —          —     

Cancelled

     —          —     

Forfeited

     (12,500     127.00   
  

 

 

   

 

 

 

Non-vested at December 31, 2013

     138,030        111.19   
  

 

 

   

 

 

 

 

9. Derivative financial instruments

 

ENXP initiated a commodity derivative policy during 2013 to utilize various derivative instruments to economically hedge its exposure to oil and natural gas price fluctuations associated with anticipated future oil and natural gas production. Additionally, ENXP’s note purchase agreement and Term Loan agreement currently requires The Company to enter into commodity derivative instruments for a minimum of 60% and maximum of 80% of anticipated production from its proved developed reserves. During the fourth quarter of 2013 the Company entered into arrangements for fixed price swaps and costless collars (puts and calls) to economically hedge future oil prices and comply with its debt instrument requirements. ENXP has not designated any of its derivative instruments as hedges; therefore, the derivatives are carried at fair value on the consolidated balance sheets as assets or liabilities and all changes in fair value are recorded as gains and losses in the statements of operations.

 

ENXP’s derivative instruments expose the Company to credit risk in the event of nonperformance by counterparties. It is the Company’s policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive market makers. ENXP evaluates the credit standing of such counterparties by reviewing their credit rating. The counterparties to the Company’s current derivative agreements have investment grade ratings.

 

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At December 31, 2013 ENXP had the following open oil derivative contracts:

 

                           Contract Price ($/Bbl)  
                                Weighted Average Price  

Year

  

Months

   Type of
Contract
   Pricing
Index
   Volume
(Bbl/d)
     Range    Swap      Floor      Ceiling  

2014

   Jan – Dec    Swap    LLS      500       $95.15 – 98.15    $ 96.24       $ —         $ —     

2015

   Jan – Dec    Collar    LLS      200       80.00 – 99.60      —           81.00         98.43   

2016

   Jan – Dec    Collar    LLS      200       71.50 – 101.60      —           71.75         100.43   

 

Pursuant to the accounting standard that permits netting of assets and liabilities where the right of offset exists, ENXP presents the fair value of derivative financial instruments on a net basis by counterparty. The gross values, prior to netting of assets and liabilities subject to master netting arrangements, and the net amounts presented in the consolidated balance sheets as of December 31, 2013 are as follows (in thousands):

 

     As of December 31, 2013(a)  

Balance Sheet Location

   Gross Amounts
Recognized
     Gross Amounts
Offset on the
Balance Sheets
    Net Amounts
Presented on the
Balance Sheets
 

Assets

       

Current Asset—Derivative Asset

   $ 33       $ (33   $ —     

Long-term Assets—Derivative Asset

     401         (401     —     
  

 

 

    

 

 

   

 

 

 

Total Assets

     434         (434     —     

Liabilities

       

Current Liability—Derivative Liability

     576         (33     543   

Long-term Liability—Derivative Liability

     415         (401     14   
  

 

 

    

 

 

   

 

 

 

Total Liability

     991         (434     557   
  

 

 

    

 

 

   

 

 

 

Net Liability

   $ 557       $ —        $ 557   
  

 

 

    

 

 

   

 

 

 

 

(a)   The Company had no derivative instruments during 2012 or 2011.

 

The following table summarizes the location and amounts of the Company’s realized and unrealized gains and losses on derivative contracts in the consolidated statements of operations (in thousands):

 

          For the
Year Ended
December 31,

2013
 

Derivatived not designated as hedging contracts

  

Location of gain or (loss) recognized in income on
derivative contracts

  

Commodity contracts:

     

Unrealized loss on commodity contracts

   Other income (expense)—Loss on derivatives    $ (557

Realized loss on commodity contracts

   Other income (expense)—Loss on derivatives      (105
     

 

 

 

Total loss on derivatives

      $ (662
     

 

 

 

 

10. Fair value measures

 

The Company follow a framework for measuring fair value, which outlines a fair value hierarchy based on the quality of inputs used to measure fair value and enhances disclosure requirements for fair value measurements.

 

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The Company uses market data, or

 

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assumptions that market participants would use, to value the asset or liability. These assumptions include market risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable.

 

The Company primarily applies the market approach for recurring fair value measurements and attempt to use the best available information. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. This hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities, a Level 1 measurement, and lowest priority to unobservable inputs, a Level 3 measurement. The three levels of fair value hierarchy are as follows:

 

   

Level 1 inputs:    Unadjusted quoted prices in active markets for identical assets or liabilities accessible to the reporting entity at the measurement date. At December 31, 2013 and 2012, the Company had no level 1 measurement.

 

   

Level 2 inputs:    Pricing inputs other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Where observable inputs are available, directly or indirectly, for substantially the full term of the asset or liability, the instrument is categorized in level 2.

 

   

Level 3 inputs:    Unobservable inputs for the asset or liability used to measure fair value to the extent that observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at measurement date. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

 

Asset and Liabilities Measured at Fair Value on a Recurring Basis

 

ENXP accounts for commodity derivatives at fair value on a recurring basis. The Company’s commodity derivative instruments consist of swaps and costless collars. At December 31, 2013, the Company estimated the fair value of its derivative instruments based on published forward commodity price curves as of the date of the estimate, less discounts to recognize present values using a pricing model which also considered market volatility, counterparty credit risk and additional criteria in determining discount rates. The discount rate used in the discounted cash flow projections was based on published LIBOR rates, Eurodollar futures rates and interest swap rates. The counterparty credit risk was determined by calculating the difference between the derivative counterparty’s bond rate and published bond rates.

 

The following tables summarize by level within the fair value hierarchy, the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of December 31, 2013 (in thousands):

 

     Fair Value Measurements Using:  
     Quoted Prices in
Active Markets
(Level 1)
     Significant Other
Observable Inputs
(Level 2)
    Significant
Unobservable
Inputs

(Level 3)
     Total  
     December 31, 2013  

Liabilities:

          

Oil derivative contracts—current

   $ —         $ (543   $ —         $ (543

Oil derivative contracts—long-term

     —           (14     —           (14
  

 

 

    

 

 

   

 

 

    

 

 

 

Total Liabilities

   $ —         $ (557   $ —         $ (557
  

 

 

    

 

 

   

 

 

    

 

 

 

 

Since the Company does not use hedge accounting for its commodity derivative contracts, any gains and losses on its assets and liabilities are included in “Loss on derivatives” in the accompanying consolidated statements of operations.

 

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The Company had no assets and liabilities measured at fair value on a recurring basis at December 31, 2012.

 

Asset and Liabilities Measured at Fair Value on a Nonrecurring Basis

 

ENXP follows the provisions of ASC 820-10, for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. This statement applies to the initial recognition of asset retirement obligations for which fair value is used.

 

The Company estimates the fair value of its ARO based on historical costs, discounted cash flow projections using numerous estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an ARO, amounts and timing of settlements, the credit-adjusted risk-free rate to be used, inflation rates as well as management’s expectation of future cost environments. As there are no corroborating market activity to support the assumptions, the Company has designated these liabilities as level 3. A reconciliation of the beginning and ending balances of the Company’s ARO is presented in Note 5—Asset Retirement Obligations.

 

Other Fair Value Measurements

 

ENXP has other financial instruments consisting primarily of cash, cash equivalents, short-term receivables and payables that approximate fair value due to the nature of the instrument and the relative short maturities.

 

11. Income Taxes

 

Income tax provision

 

The Company estimates its federal and state income tax provision based on current tax law. The reported tax provision differs from the amounts currently receivable or payable because certain income and expense items are recognized in different time periods for financial reporting purposes than for income tax purposes. The following is a summary of the Company’s provision for income taxes (in thousands):

 

     Year Ended December 31,  
     2011     2012     2013  

Current

      

Federal

   $ —        $ (8,297   $ 8,073   

State

     (29     (233     20   
  

 

 

   

 

 

   

 

 

 
     (29     (8,530     8,093   

Deferred

      

Federal

     —          1,052        (838

State

     —          64        (278
  

 

 

   

 

 

   

 

 

 
     —          1,116        (1,116
  

 

 

   

 

 

   

 

 

 

Income tax benefit (expense)(1):

   $ (29   $ (7,414   $ 6,977   
  

 

 

   

 

 

   

 

 

 

 

(1)   Excludes $1.6 million related to tax penalties and interest accrued in the year ended December 31, 2013 related to delinquent tax filings for the 2012 tax year.

 

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The Company’s income tax provision is based on its results of operations. The Company has recorded deferred federal and state income tax assets and liabilities attributable to the differences in the bases in its assets for U.S. GAAP and for federal and state taxation purposes upon our conversion to a C Corporation. A reconciliation of the statutory federal tax provision to the Company’s income tax provision in the accompanying financial statements is as follows (in thousands):

 

     Year Ended December 31,  
     2011     2012     2013  

Statutory federal provision (35%)

   $ —        $ (5,653   $ 10,060   

Federal tax provision attributed to period we were not directly subject to federal taxation

     —          (464     —     

Statutory state income tax provision, net of federal tax benefit in 2012

     (29     (114     (168

Surtax exemption on NOL carryback

     —          —          (160

Change in valuation allowance

         (2,201

Tax effect of expenses not deductible for federal or state taxation

     —          (22     (554

Recognition of temporary differences upon change in tax status

     —          (1,161     —     
  

 

 

   

 

 

   

 

 

 

Income tax benefit (expense) before tax penalties and interests

   $ (29   $ (7,414   $ 6,977   

Penalties and interests(1)

     —          —          (1,626
  

 

 

   

 

 

   

 

 

 

Income tax benefit (expense)

   $ (29   $ (7,414   $ 5,351   
  

 

 

   

 

 

   

 

 

 

 

(1)   Penalties and interest on late tax filing.

 

The Company recognizes interest and penalties accrued to unrecognized benefits in Income tax benefit (expense) in its consolidated statements of operations. For the years ended December 31, 2013, 2012 and 2011, the Company recognized no interest and penalties related to unrecognized benefits.

 

As of December 31, 2013, the Company has available, to reduce future taxable income, a United States net operating loss carryforward (NOLs) of approximately $23.7 million before consideration of any valuation allowance, which expires in the year 2033. No portion of these net operating loss carryforwards are subject to the ownership change limitation provisions of Section 382 of the Internal Revenue Code (IRC).

 

The Company assesses the recoverability of its deferred tax assets each period by considering whether it is more likely than not that all or a portion of the deferred tax assets will not be realized. The Company considers all available evidence (both positive and negative) in determining whether a valuation allowance is required. During 2013 the Company established a valuation allowance of $2.2 million for the portion of its deferred tax assets which may not provide a realized benefit to future periods for the year ended December 31, 2013.

 

On September 13, 2013, the United States Treasury Department and the Internal Revenue Service issued final tangible property regulations (the tangible property regulations) under provisions that include IRC Sections 162, 167 and 263(a). The tangible property regulations apply to amounts paid to acquire, produce or improve tangible property, as well as dispositions of such property. The general effective date of the tangible property regulations are for tax years beginning on or after January 1, 2014. The Company may be required to make tax accounting method changes as of January 1, 2014; however, based on the Company’s analysis to date management does not anticipate the impacts of the tangible property regulations to be material to the Company’s consolidated financial position, its results of operations, or both.

 

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Deferred Tax Assets/Liabilities

 

The tax effects of temporary differences between reported earnings and taxable earnings consisted of the following (in thousands):

 

     December 31,  
     2012     2013  

Deferred Tax Assets:

    

Current

    

Asset retirement obligations

     6        234   

Derivative gains and losses

     —          190   

Other (net)—accrued expenses

     (145     (103
  

 

 

   

 

 

 

Current deferred tax assets (liability),

     (139     321   
  

 

 

   

 

 

 

Valuation allowance

     —          (50
  

 

 

   

 

 

 

Current deferred tax assets

     (139     271   
  

 

 

   

 

 

 

Non-Current

    

Asset retirement obligations

     —          227   

Derivative gains and losses

     —          5   

Oil & gas properties

     533        (10,827

Net operating loss carryforwards

     —          8,297   

Share-based compensation

     722        4,118   

Other (net)

     —          60   
  

 

 

   

 

 

 

Non-current deferred tax assets, net

     1,255        1,880   
  

 

 

   

 

 

 

Valuation allowance

     —          (2,151
  

 

 

   

 

 

 

Non-current deferred tax assets

     1,255        (271
  

 

 

   

 

 

 

Total deferred tax assets

     1,116        0   
  

 

 

   

 

 

 

 

12. Earnings Per Share

 

Earnings (Loss) Per Share.    The two-class method of computing net earnings per share is required for those entities that have participating securities. The two-class method is an earnings allocation formula that determines net earnings per share for participating securities according to dividends declared (or accumulated) and participation rights in undistributed earnings. ENXP’s restricted shares of common stock, See Note 8—Share based compensation for additional discussion, are participating securities under ASC 260, Earnings Per Share, because they may participate in undistributed earnings with common stock.

 

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The following table shows the computation of basic and diluted net earnings (loss) per share for the years ended December 31, 2013 and 2012 (dollars in thousands, except for share and per share amounts):

 

     Year Ended December 31,  
     2011     2012      2013  

Net income (loss)

   $ (1,478   $ 8,734       $ (21,767
  

 

 

   

 

 

    

 

 

 

Weighted average number of shares used to calculate basic and diluted net income per share:

       

Weighted average number of unrestricted outstanding common shares

     397,500        397,500         372,500   

Effect of unvested restricted stock awards

     —          36,687         132,296   
  

 

 

   

 

 

    

 

 

 

Denominator for basic earnings per common share

     397,500        434,187         504,796   
  

 

 

   

 

 

    

 

 

 

Denominator for diluted earnings per common share(1):

     397,500        434,187         504,796   
  

 

 

   

 

 

    

 

 

 

Net earnings per common share:

       

Basic

   $ (3.72   $ 20.12       $ (43.12

Diluted(1):

   $ (3.72   $ 20.12       $ (43.12

 

(1)   The potentially dilutive impact of the warrants to purchase 269,231 shares of the Company’s mandatory redeemable preferred stock issued during 2013 were excluded from this calculation as they were antidilutive for the year ended December 31, 2013.

 

13. Commitments and Contingencies

 

The Company’s contractual obligations include notes payable, operating lease obligations related to office space, certain vehicles, and office equipment, and asset retirement obligations. During the year ended December 31, 2013, there were no material changes to the Company’s contractual obligations, other than changes related to its senior unsecured notes, its Chesapeake notes, and the extinguishment of the Company’s $21.4 million notes payable with Guggenheim. Other contractual obligations are consistent with the December 31, 2012 levels and contain various expiration dates through 2018.

 

We had the following contractual obligations and commitments as of December 31, 2013 (in thousands):

 

    Obligations and Commitments Due By Period  
    Total     2014     2015     2016     2017     2018     Thereafter  

Senior unsecured notes

    165,000        —          —          —          —          165,000        —     

Subordinated Chesapeake note(1)

    30,798        —          —          —          —          30,798        —     

Interest expense on senior unsecured notes

    118,150        25,094        25,094        25,163        30,371        12,428        —     

Contractual lease payments

    851        436        415        —          —          —          —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

Total contractual obligations

  $ 314,798      $ 25,530      $ 25,509      $ 25,163      $ 30,371      $ 208,226      $ —     
 

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)   Includes $14.4 million of interest paid or to be paid in kind.

 

Litigation

 

ENXP, from time to time, is involved in various claims, lawsuits, and disputes with third parties, actions involving allegations of fraud, discrimination, or breach of contract incidental to operations of its business. The Company is not currently involved in any litigation which management believes could have a materially adverse effect on its financial condition or results of operations.

 

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14. Related Party Transactions

 

On December 1, 2013, the Company entered into a joint operating agreement with Energy & Exploration Partners, LP for the purpose of developing two Eaglebine wells, the Su-Ling #1 and the Bonanza # IH. Energy &Exploration Partners, LP invested $200,000 in Su-Ling #1 and $400,000 in Bonanza #lH, with its working interest percentage in each well equal to the amount of the respective investment divided by the drilling and completion cost for the well. B. Hunt Pettit, the Company ‘s President, Chief Executive Officer and director is also the sole limited partner of Energy & Exploration Partners, LP and the sole member of its general partner, Septa Holdings LLC. Prior to entering into the joint operating agreement with Energy & Exploration Partners, LP, the Company’s board of directors approved the transaction with a view that there would be no further joint investments in operations with any of its officers, directors or employees.

 

15. Subsequent Events

 

Tranche C Notes.    On January 31, 2014 the Company entered into the second supplement to the notes purchase agreement and issued $15.0 million of senior unsecured notes, which are referred to as the Tranche C notes. The Tranche C notes mature on December 12, 2018. From January 31, 2014 through January 30, 2018, the Tranche C notes bear interest at a rate equal to the greater of (i) 15% per year and (ii) the annual rate payable under the term loan agreement plus 2%. If not earlier refinanced, the interest rate on the Tranche C notes from January 31, 2018 to December 12, 2018 will be the greater of (i) 20% per year and (ii) the annual rate payable under the term loan agreement plus 2%.

 

The Tranche C notes are subject to prepayment penalties if repaid on or before April 8, 2016. For any prepayments made on or prior to October 8, 2015, the Company must pay a make-whole amount equal to the present value of the interest payable on the principal balance of the prepaid Tranche C notes, as applicable, from the date of prepayment through October 8, 2015, discounted at a rate equal to the yield to maturity for the applicable United States treasury securities plus 50 basis point. For any prepayments made on or before April 8, 2016, the Company must pay a prepayment premium equal to 3% of the outstanding principal amount repaid.

 

Tranche D Notes.    On March 27, 2014 the Company entered into the third supplement to the notes purchase agreement for $60.0 million, which we refer to as the Tranche D notes. The Company issued an aggregate of $45.0 million of senior unsecured notes in the initial funding on March 27, 2014 and has an option, subject to achievement of certain conditions precedent, to issue additional notes in the aggregate amount of $15.0 million in future periods, but no later than September 30, 2014. The initial March 2014 funding of Tranche D notes will mature on March 27, 2019 and will bear interest from the date of funding until March 26, 2018 at a rate of 15% per year. Thereafter, the interest rate will increase to 20% until maturity of the initial Tranche D notes.

 

The Tranche D notes are subject to prepayment penalties if repaid on or before March 27, 2017. For any prepayments made on or prior to September 27, 2016, the Company must pay a make-whole amount equal to the present value of the interest payable on the principal balance of the prepaid Tranche D notes from the date of prepayment through September 27, 2016, discounted at a rate equal to the yield to maturity for the applicable United States treasury securities plus 50 basis point. For any prepayments made on or before March 27, 2017, the Company must pay a prepayment premium equal to 3% of the outstanding principal amount repaid.

 

In connection with the issuance of the Tranche D notes in March 2014, the Company issued 71,122 of additional shares of our mandatorily convertible preferred stock at an exercise price of $0.01 per share. The fair value of $3.6 million for the warrants will be recorded as a discount to the value of the Tranche D notes.

 

Management has evaluated subsequent events through April 4, 2014, the date these combined and consolidated financial statements were available to be issued. No events or transactions other than those already described in these financials have occurred subsequent to the balance sheet date that might require recognition or disclosure in the consolidated financial statements.

 

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16. Supplemental oil and natural gas reserves and standardized measure information (Unaudited)

 

General

 

Prior to the first quarter of 2012, the Company was primarily engaged in the purchase and sale of leasehold acreage, and did not recognize reserve quantities or production. However, during 2012 the Company adopted a business strategy and commenced participation in drilling and producing activities that resulted in proved reserves and production during the years ended December 31, 2012 and 2013.

 

Geographic Area of Operation

 

The Company’s proved reserves are located within the United States onshore, and the following disclosures about costs incurred, results of operations and proved reserves are on a total-company basis.

 

Capitalized Costs

 

The total amount of capitalized costs related to oil and natural gas producing activities and the total amount of related accumulated depletion, depreciation and accretion are as follows (in thousands):

 

     As of
December 31,
 
     2012     2013  

Capitalized Costs

    

Unproved Properties(1)

   $ 31,175      $ 89,086   

Proved Properties(1)(2)

     6,059        158,955   
  

 

 

   

 

 

 
     37,234        248,041   

Accumulated depletion, depreciation and amortization(2)

     (4,264     (19,368
  

 

 

   

 

 

 
   $ 32,970      $ 228,673   
  

 

 

   

 

 

 

 

(1)   Costs associated with unproved properties relates to the Company’s costs in leasehold interests. During the years ended December 31, 2013, the Company recognized leasehold impairment expense of $18.5 million and transferred the impairment costs from unproved properties to proved properties.
(2)   For the periods ended December 31, 2013 and 2012, the Company performed the full-cost ceiling test in accordance with the full-cost method of accounting to determine if its proved properties exceeded the ceiling limitation. As a result, the Company recognized full-cost ceiling impairments of $8.4 million and $4.0 million, respectively.

 

Capitalized Costs, Not Subject to Amortization

 

Costs not subject to amortization relate to unproved properties which are excluded from amortizable capital costs until it is determined that proved reserves can be assigned to such properties or until such time as the Company has made an evaluation that impairment has occurred. Subject to industry conditions, evaluation of most of these properties is expected to be completed within one to five years. The following table provides a summary of costs that are not being amortized as of December 31, 2013, by the year in which the costs were incurred (in thousands):

 

      Year Incurred      As of
December, 31
2013
 
   2011  &
Prior
     2012      2013     

Costs excluded from amortization by year incurred:

           

Acquisition costs

   $ 17,902       $ 3,914       $ 63,323       $ 85,139   

Exploration costs. .

     —           —           404         404   

Capitalized interest

     —           58         3,485         3,543   
  

 

 

    

 

 

    

 

 

    

 

 

 

Total costs not subject to amortization

   $ 17,902       $ 3,972       $ 67,212       $ 89,086   
  

 

 

    

 

 

    

 

 

    

 

 

 

 

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Costs Incurred In Oil and Gas Property Acquisition, Exploration and Development Activities

 

The following costs were incurred in oil and gas acquisition, exploration, and development activities (in thousands):

 

      2011      2012      2013  

Costs incurred:

        

Unproved property acquisition costs(1)

   $ 18,866       $ 3,971       $ 66,708   

Exploration costs

     —           —           107,678   

Development costs

     —           —           42,022   
  

 

 

    

 

 

    

 

 

 
   $ 18,866       $ 3,971       $ 216,408   
  

 

 

    

 

 

    

 

 

 

 

(1)   Includes seismic cost of $5.7 million and $1.2 million incurred during the years ended December 31, 2013 and 2012, respectively.

 

Depreciation, Depletion, Amortization and Accretion

 

Depreciation, depletion, amortization and accretion expense per barrel of oil equivalent (“Boe”) of products sold during the period ending December 31, 2013 and 2012 was $35.34 per Boe and $93.49 per Boe, respectively. The Company had no interests in producing properties and related production for the period ended December 31, 2011.

 

Oil and Natural Gas Reserve Information

 

The Company has adopted certain amendments to the Extractive Activities – Oil and Gas topic of the Codification that updated and aligned the FASB’s reserve estimation and disclosure requirements for oil and natural gas companies with the reserve estimation and disclosure requirements that were adopted by the SEC in December 2008. In accordance with these rules, the Company uses the average of first-day-of-the-month commodity prices over the preceding 12-month period when estimating quantities of proved reserves. Similarly, such prices are used to calculate the standardized measure of discounted future cash flows and values used in the ceiling test impairment.

 

There are numerous uncertainties in estimating quantities of proved reserves and in providing the future rates of production expenditures. The following reserve data represent estimates only and are inherently imprecise and may be subject to substantial revisions as additional information such as reservoir performance, additional drilling, technological advancements and other factors become available. Decreases in the prices of oil and natural gas could have an adverse effect on the carrying value of the Company’s proved reserves, reserve volumes and our revenues, profitability and cash flow.

 

As of December 31, 2013, all of the Company’s reserves were owned by our wholly-owned subsidiary, Energy and Exploration Partners, LLC.

 

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The following sets forth estimated quantities of the Company’s net proved and proved developed oil and natural gas reserves:

 

     Oil
(Bbls)(1)
    NGL
(Bbls)(1)
    Natural
Gas
(Mcf)(1)(8)
    Oil
Equivalent
(Boe)(2)
 

Proved reserves as of December 31, 2011(3)

     —          —          —          —     

Extensions and discoveries(4)

     25,556        384        52,827        34,744   

Revisions of previous estimates

     —          —          —          —     

Purchase of minerals in place

     —          —          —          —     

Sales of reserves

     —          —          —          —     

Production

     (2,247     (384     (3,903     (3,281
  

 

 

   

 

 

   

 

 

   

 

 

 

Proved reserves as of December 31, 2012

     23,309        —          48,924        31,463   

Extensions and discoveries(4)

     5,761,777        470        6,513,374        6,847,809   

Revisions of previous estimates(5)

     (16,567     —          (29,679     (21,514

Purchase of minerals in place(6)

     256,300        4,544        801,269        394,389   

Sales of reserves(7)

     (4,581     109        (16,970     (7,300

Production

     (161,579     (5,123     (128,603     (188,136
  

 

 

   

 

 

   

 

 

   

 

 

 

Proved reserves as of December 31, 2013

     5,858,659        —          7,188,315        7,056,711   
  

 

 

   

 

 

   

 

 

   

 

 

 

Year-end proved developed reserves:

        

2011

     —          —          —          —     

2012

     23,309        —          48,924        31,463   

2013

     1,946,997        —          2,896,678        2,429,776   

Year-end proved undeveloped reserves:

        

2011

     —          —          —          —     

2012

     —          —          —          —     

2013

     3,911,662        —          4,291,637        4,626,935   

 

(1) Estimated reserves as of December 31, 2013 and 2012 are based on the unweighted arithmetic average of first-day-of- the-month commodity prices over the period January through December for each applicable period in accordance with current definitions and guidelines set forth by the SEC and the FASB.
(2) Boe is determined using the ratio of six thousand cubic feet (“Mcf”) of natural gas to one barrel (“Bbl”) of crude oil.
(3) The Company had no proved reserves in 2011 or prior.
(4) Discoveries and extensions during the years ended December 31, 2012 and 2013 were primarily discoveries resulting from our participation in the drilling of three gross successful exploratory wells during 2012 and fifteen gross productive exploratory wells during 2013.
(5) Revisions of previous estimates of reserves during the year ended December 31, 2013 were primarily from a reduction in reserve estimates of 1 gross (0.25 net) non-operated well that began production in late 2012 and subsequently declined at a faster rate than anticipated.
(6) The purchase of minerals in place during the year ended December 31, 2013 was related to the Company’s acquisition of acreage in the Eaglebine from Chesapeake, including interests in proved developed oil and natural gas reserves.
(7) Sales of reserves during the year ended December 31, 2013 were a result of the sale of our DJ Basin assets located in Weld County, Colorado, which included 2 gross (0.09 net) wells.
(8) The Company’s natural gas reserves include immaterial NGL reserves.

 

Standardized Measure of Discounted Future Net Cash Flows

 

The following presents the standardized measure of discounted future net cash flows related to the Company’s proved oil and natural gas reserves together with changes therein, as defined by the FASB as of December 31, 2013 and 2012. The Company did not own any producing wells or proved reserves on or prior to

 

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December 31, 2011. Future cash inflows represent expected revenues from production of period-end quantities of proved reserves based on the unweighted arithmetic average of first-day-of-the-month commodity prices for January through December of each annual period. All prices are adjusted by lease for quality, transportation fees, energy content and regional price differentials. The average adjusted commodity prices related to the oil are $91.68 per barrel and $95.16 per barrel for the periods ended December 31 2012 and 2013, respectively. The average adjusted commodity prices related to the natural gas are $3.34 per Mcf and $3.39 per Mcf for the periods ended December 31 2012 and 2013, respectively.

 

Future cash inflows were reduced by estimated future production and development costs based on current costs with no escalation to determine pre-tax cash inflows. Additionally, immaterial estimated future abandonment costs for the year ended December 31, 2013 were not included in the estimate of future cash flows. Estimated future abandonment costs for the year-ended December 31, 2012 were not material and were not included in the estimate of future cash flows. Future income taxes were computed by applying the statutory tax rate to the excess of net cash inflows over our tax basis in the associated proved oil and natural gas properties. Net operating loss carryforwards were also considered in the future income tax calculation. Future net cash inflows after income taxes were discounted using a 10% annual discount rate to arrive at the Standardized Measure.

 

     December 31,  
     2012     2013  
     (in thousands)  

Future cash inflows

   $ 2,300      $ 581,835   

Future production costs

     (1,019     (161,665

Future development costs

     —          (125,725

Future income tax expense

     (372     (72,975
  

 

 

   

 

 

 

Net future cash flows before discount

     909        221,470   

Annual discount of 10% for estimated timing of cash flows

     (271     (107,584
  

 

 

   

 

 

 

Standardized measure of discounted future net cash flows

   $ 638      $ 113,886   
  

 

 

   

 

 

 

 

The following are the principal sources of changes in the standardized measure of discounted future net cash flows of the Company for each of the two years in the period ended December 31 (in thousands):

 

     December 31,  
     2012     2013  

Beginning of year

   $ —        $ 638   

Sales of oil and natural gas produced, net of production costs

     (191     (12,357

Purchase of minerals in place

     —          12,018   

Sales of minerals in place

     —          (213

Extensions and discoveries

     1,066        149,360   

Change in income taxes, net

     (237     (34,922

Changes in prices and costs

     —          (494

Revisions of previous estimates

     —          (977

Accretion of discount

     —          88   

Changes in production rates and other

     —          745   
  

 

 

   

 

 

 

End of the year

   $ 638      $ 113,886   
  

 

 

   

 

 

 

 

* * * * * * *

 

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17. Quarterly Financial Data (Unaudited)

 

The following table summarizes results for each of the four quarters in the years ended December 31, 2013, 2012 & 2011 (in thousands, except for share and per share amounts):

 

     Quarters Ended  
     March 31     June 30     September 30     December 31  

2013

        

Revenues

   $ 137      $ 1,805      $ 5,043      $ 9,452   

Operating loss

   $ (13,240   $ (4,516   $ (1,077   $ (1,063

Net income (loss)

   $ 150      $ (9,582   $ (6,158   $ (6,177

Net income (loss) per common share (1):

        

Basic and diluted

   $ 0.30      $ (19.08   $ (12.20   $ (12.06

Weighted average common shares outstanding:

        

Basic and diluted

     500,000        502,113        504,886        512,051   

 

     Quarters Ended  
     March 31     June 30     September 30     December 31  

2012

        

Revenues

   $ 30      $ 81      $ 39      $ 66   

Operating loss

   $ (680   $ (1,003   $ (6,177   $ (6,913

Net income (loss)

   $ (1,206   $ 1,590      $ 13,893      $ (5,543

Net income (loss) per common share (1):

        

Basic and diluted

   $ 3.03      $ 4.00      $ 31.51      $ 11.09   

Weighted average common shares outstanding:

        

Basic and diluted

     397,500        397,500        440,951        500,000   

 

     Quarters Ended  
     March 31     June 30     September 30     December 31  

2011

        

Revenues

   $ —        $ —        $ —        $ —     

Operating loss

   $ (193   $ (166   $ (293   $ (1,125

Net income (loss)

   $ 367      $ (111   $ (302   $ (1,432

Net income (loss) per common share (1):

        

Pro forma Basic and diluted

   $ 0.92      $ (0.28   $ (0.76   $ (3.60

Weighted average common shares outstanding:

        

Pro forma Basic and diluted

     397,500        397,500        397,500        397,500   

 

(1)   The sum of the individual quarterly net loss amounts per share may not agree with year-to-date net loss per share as each quarterly computation is based on the net income or loss for that quarter and the weighted-average number of shares outstanding during that quarter.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

BALANCE SHEETS

JUNE 30, 2014 AND DECEMBER 31, 2013

 

     June 30,
2014
    December 31,
2013
 
     (Unaudited)        

Assets

    

Current Assets

    

Cash and Cash Equivalents

   $ 12,340,501      $ 6,845,661   

Oil and Gas Sales Receivable

     27,009,854        14,599,245   

Accounts Receivable

     920,425        610,521   

Commodity Derivative Instruments at Fair Value

     6,360        —     

Prepaid Expenses and Other Current Assets

     100,817        154,737   
  

 

 

   

 

 

 

Total Current Assets

     40,377,957        22,210,164   
  

 

 

   

 

 

 

Property and Equipment

    

Full Cost Used for Oil and Gas Properties:

    

Proved Properties Being Amortized

     192,278,805        139,656,920   

Unproved Properties Not Subject to Amortization

     18,101,073        410,217   

Other Property and Equipment

     73,649        73,649   
  

 

 

   

 

 

 
     210,453,527        140,140,786   

Less: Accumulated Depreciation, Depletion, and Amortization

     (38,888,186     (21,534,715
  

 

 

   

 

 

 

Total Property and Equipment, Net

     171,565,341        118,606,071   
  

 

 

   

 

 

 

Other Assets

    

Deposits

     —          8,136   
  

 

 

   

 

 

 

Total Other Assets

     —          8,136   
  

 

 

   

 

 

 

Total Assets

   $ 211,943,298      $ 140,824,371   
  

 

 

   

 

 

 

Liabilities and Members’ Capital

    

Current Liabilities

    

Accounts Payable and Accrued Expenses

   $ 21,020,894      $ 11,162,543   

Revenue and Royalties Payable

     12,636,301        7,538,126   

Commodity Derivative Instruments at Fair Value

     8,166,094        3,443,968   
  

 

 

   

 

 

 

Total Current Liabilities

     41,823,289        22,144,637   
  

 

 

   

 

 

 

Long-Term Liabilities

    

Notes Payable

     19,000,000        23,400,000   

Commodity Derivative Instruments at Fair Value

     1,558,691        —     

Asset Retirement Obligations

     4,454,301        4,265,600   
  

 

 

   

 

 

 

Total Long-Term Liabilities

     25,012,992        27,665,600   
  

 

 

   

 

 

 

Total Liabilities

     66,836,281        49,810,237   
  

 

 

   

 

 

 

Members’ Capital

     145,107,017        91,014,134   
  

 

 

   

 

 

 

Total Liabilities and Members’ Capital

   $ 211,943,298      $ 140,824,371   
  

 

 

   

 

 

 

 

See accompanying notes to these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

STATEMENTS OF OPERATIONS

(Unaudited)

 

     Three Months Ended
June 30,
    Six Months Ended
June 30,
 
     2014     2013     2014     2013  

Revenue

        

Oil and Gas Revenue, Net of Royalties

   $ 60,589,211      $ 17,192,505      $ 98,470,472      $ 28,648,032   

Realized Losses on Commodity Derivative Instruments

     (3,188,631     (14,904     (4,045,771     (14,904
  

 

 

   

 

 

   

 

 

   

 

 

 

Total Revenue

     57,400,580        17,177,601        94,424,701        28,633,128   
  

 

 

   

 

 

   

 

 

   

 

 

 

Operating Expenses

        

Lease Operating Expenses

     6,316,482        2,027,905        9,674,565        3,230,347   

Depreciation, Depletion, and Amortization

     10,553,906        3,896,983        17,353,471        8,327,334   

Production Taxes

     2,933,084        820,394        4,749,115        1,358,694   

Acquisition Expenses

     83,700        784,384        190,861        1,717,193   

Accretion Expenses

     32,064        25,194        63,698        46,959   

General and Administrative

     784,913        892,485        1,709,017        1,554,046   
  

 

 

   

 

 

   

 

 

   

 

 

 

Total Operating Expenses

     20,704,149        8,447,345        33,740,727        16,234,573   
  

 

 

   

 

 

   

 

 

   

 

 

 

Operating Income

     36,696,431        8,730,256        60,683,974        12,398,555   
  

 

 

   

 

 

   

 

 

   

 

 

 

Other Income (Expense)

        

Interest Expense

     (129,712     (191,437     (316,634     (287,212

Unrealized Gains (Losses) on Commodity Derivative Instruments

     (4,944,285     898,513        (6,274,457     (42,350
  

 

 

   

 

 

   

 

 

   

 

 

 

Total Other Income (Expense)

     (5,073,997     707,076        (6,591,091     (329,562
  

 

 

   

 

 

   

 

 

   

 

 

 

Net Income

   $ 31,622,434      $ 9,437,332      $ 54,092,883      $ 12,068,993   
  

 

 

   

 

 

   

 

 

   

 

 

 

 

See accompanying notes to these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

STATEMENTS OF CHANGES IN MEMBERS’ CAPITAL

 

     Series A
Units
     Series  B
Units
     Member
Contributions
     Retained
Earnings
     Total  
              

Balance, December 31, 2012

     41,913         637       $ 42,450,000       $ 1,236,329       $ 43,686,329   

Net Income for the Period

     —           —           —           12,068,993         12,068,993   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Balance, June 30, 2013

     41,913         637         42,450,000         13,305,322         55,755,322   

Net Income for the Period

     —           —           —           35,258,812         35,258,812   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Balance, December 31, 2013

     41,913         637         42,450,000         48,564,134         91,014,134   

Net Income for the Period

     —           —           —           54,092,883         54,092,883   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

Balance, June 30, 2014

     41,913         637       $ 42,450,000       $ 102,657,017       $ 145,107,017   
  

 

 

    

 

 

    

 

 

    

 

 

    

 

 

 

 

 

 

See accompanying notes to these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

STATEMENTS OF CASH FLOWS

(Unaudited)

 

    Three Months Ended
June 30,
    Six Months Ended
June 30,
 
    2014     2013     2014     2013  

Cash Flows from Operating Activities

       

Net Income

  $ 31,622,434      $ 9,437,332      $ 54,092,883      $ 12,068,993   

Adjustments to Reconcile Net lncome to Net Cash Provided by Operating Activities

       

Depreciation, Depletion, and Amortization

    10,553,906        3,896,983        17,353,471        8,327,334   

Accretion Expense

    32,064        25,194        63,698        46,959   

Unrealized Losses (Gains) on Commodity Derivative Instruments

    4,944,285        (898,513     6,274,457        42,350   

Increase in Oil and Gas Sales Receivable

    (9,964,536     (2,296,662     (12,410,609     (1,971,008

Increase in Accounts Receivable

    (890,238     (193,442     (309,904     (76,080

(Increase) Decrease in Prepaid Expenses and Other Current Assets

    (25,407     (68,730     53,920        193,347   

Increase in Accounts Payable and Accrued Expenses

    9,576,485        1,000,720        9,193,995        667,699   

Increase in Revenue and Royalties Payable

    4,044,065        1,418,133        5,098,175        2,040,251   
 

 

 

   

 

 

   

 

 

   

 

 

 

Net Cash Provided by Operating Activities

    49,893,058        12,321,015        79,410,086        21,339,845   
 

 

 

   

 

 

   

 

 

   

 

 

 

Cash Flows from Investing Activities

       

Acquisition and Development of Oil and Gas Properties

    (44,286,082     (18,035,574     (69,523,382     (36,069,339

Decrease in Deposits

    1,394        —          8,136        25,000   
 

 

 

   

 

 

   

 

 

   

 

 

 

Net Cash Used in Investing Activities

    (44,284,688     (18,035,574     (69,515,246     (36,044,339
 

 

 

   

 

 

   

 

 

   

 

 

 

Cash Flows from Financing Activities

       

Proceeds from Notes Payable

    6,700,000        8,000,000        6,900,000        14,900,000   

Repayments on Notes Payable

    (11,100,000     —          (11,300,000     —     

(Decrease) Increase in Advances from Working Interest Owners

    (270,216     36,827        —          41,074   
 

 

 

   

 

 

   

 

 

   

 

 

 

Net Cash (Used in) Provided by Financing Activities

    (4,670,216     8,036,827        (4,400,000     14,941,074   
 

 

 

   

 

 

   

 

 

   

 

 

 

Net Increase in Cash and Cash Equivalents

    938,154        2,322,268        5,494,840        236,580   

Cash and Cash Equivalents, Beginning

    11,402,347        3,614,149        6,845,661        5,699,837   
 

 

 

   

 

 

   

 

 

   

 

 

 

Cash and Cash Equivalents, Ending

  $ 12,340,501      $ 5,936,417      $ 12,340,501      $ 5,936,417   
 

 

 

   

 

 

   

 

 

   

 

 

 

Supplemental Disclosures of Cash Flow Information

       

Cash Paid for Interest

  $ 129,712      $ 8,297      $ 316,634      $ 251,177   

Non Cash Asset Retirement Obligations Capitalized

    125,003        300,008        125,003        350,007   

Non Cash Accruals for Capital Expenditures

    664,356        670,696        664,356        916,703   

 

 

See accompanying notes to these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies

 

Treadstone Energy Partners, LLC (the Company), is an independent oil and gas company engaged primarily in the acquisition, exploration, development, and production of crude oil and natural gas in the State of Texas. The Company was formed as a Delaware limited liability company on February 24, 2011.

 

Basis of Presentation

 

The accompanying financial statements have been prepared on the accrual basis of accounting in accordance with accounting principles generally accepted in the United States of America (GAAP).

 

Cash and Cash Equivalents

 

For the purpose of the statement of cash flows, the Company considers all highly liquid investments with a maturity of three months or less to be cash equivalents. As of June 30, 2014 and December 31, 2013, the Company did not have any short-term investments classified as cash equivalents.

 

Accounts Receivable

 

Accounts receivable consist of uncollateralized oil and natural gas revenues due under normal trade terms, as well as amounts due from working interest owners of oil and gas properties for their share of expenses paid on their behalf by the Company. Management reviews receivables periodically and reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount that may not be collectible. As of June 30, 2014 and December 31, 2013, the valuation allowance was $-0-.

 

Oil and Gas Producing Activities

 

The Company follows the full cost method of accounting for oil and gas properties. Under the full cost method, all costs associated with property acquisition, exploration, and development activities are capitalized. Capitalized costs include lease acquisitions, geological and geophysical work, delay rentals, costs of drilling, completing, and equipping successful and unsuccessful oil and gas wells, and directly related costs.

 

Once evaluated, all capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves and the estimated cost of dismantlement and abandonment, net of salvage value, are amortized on the units-of-production method using estimates of proved reserves. Investments in unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized.

 

Costs associated with unproved properties and properties under development are excluded from the full cost amortization base until the properties have been evaluated. Unproved properties are transferred into the full cost pool subject to amortization when management determines that a field has been evaluated through drilling operations or a thorough geologic evaluation.

 

In addition, the capitalized costs are subject to a “ceiling test”, which basically limits such costs to the aggregate of the “estimated present value”, discounted at a ten percent (10%) interest rate of future net revenues from proved reserves, based on current economic and operating conditions, plus the lower of cost or fair market value of unproved properties.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies (Continued)

 

Oil and Gas Producing Activities (Continued)

 

Sales of proved and unproved properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. Abandonment of properties is accounted for as adjustments of capitalized costs with no loss recognized.

 

The Company follows the guidance of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) No. 2010-03, Extractive Activities—Oil and Gas (Topic) 932. This ASU provides estimation and disclosure requirements for oil and gas reserves, designed to align them with the requirements of the Securities and Exchange Commission (SEC). The guidance, among other purposes, is primarily intended to provide investors with a more meaningful and comprehensive understanding of oil and gas producing activities, updating the definition of proved oil and gas reserves to indicate that entities must use the average, first-day-of-the-month price during the 12-month period before the ending date of the period covered by the report, disclosing geographical areas that represent a certain percentage of proved reserves, updating the reserve estimation requirements for changes in practice and technology that have occurred over the past several decades, and requiring an entity to disclose separately the amounts and quantities for consolidated and equity method investments.

 

Depreciation, depletion, and amortization (DD&A) is computed on the units-of- production method. DD&A expense includes the amounts computed on capitalized future plugging and abandonment costs. Depreciation, depletion, and amortization expense for the Company’s oil and gas properties totaled $10,553,906, $3,894,914, $17,353,471 and $8,325,264, respectively, for the three and six months ended June 30, 2014 and 2013.

 

Other Property and Equipment

 

Other property and equipment, which includes office furniture and equipment, is depreciated using the straight-line method over the estimated useful lives of the assets ranging from three to ten years. Gain or loss on retirement, sale, or other disposition of these assets is included in income in the period of disposition. Costs of major repairs that extend the useful life are capitalized. Costs for maintenance and repairs are expensed as incurred.

 

Revenue Recognition

 

The Company recognizes oil and gas revenue from its interests in producing wells using the sales method. Under this method, revenues are recognized based on actual volumes of oil and gas produced and delivered to purchasers. As a result, the Company accrues revenue relating to production for which the Company has not yet received payment.

 

Hedging Agreements

 

The Company manages the potential impact of changes in the price of oil and natural gas by entering into derivative commodity instruments (hedges), but does not use them for speculative purposes.

 

The Company accounts for hedging agreements in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 815. ASC 815 requires the Company to recognize all derivative instruments on the balance sheet as either an asset or liability, measured at fair value, and requires that changes in a derivative’s fair value be realized currently in earnings, unless hedge accounting criteria are met.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies (Continued)

 

Hedging Agreements (Continued)

 

The Company’s hedges are specifically referenced to the NYMEX index prices received for its designated production. Estimating the fair value of derivatives requires complex calculations incorporating estimates of future prices, discount rates, and price movements. As a result, the Company obtains the fair value of its commodity derivatives from the counterparties to those contracts. Because the counterparties are market makers, they are able to provide a literal market value, or what they would be willing to settle such contracts for as of the given date.

 

Asset Retirement Obligations

 

The Company accounts for future plugging and abandonment costs in accordance with FASB ASC 410. ASC 410 requires legal obligations associated with the retirement of long-lived assets (i.e., future plugging and abandonment costs) to be recognized at their fair value at the time the obligations are incurred. Upon initial recognition of the liability, that cost is capitalized as part of the carrying amount of the related long-lived asset. The estimate of future plugging and abandonment costs is highly subjective. Management’s current estimate of the Company’s share of such future costs is approximately $4,454,301 and $4,265,600, as of June 30, 2014 and December 31, 2013, respectively.

 

Long-Lived Assets

 

The Company continually evaluates the recoverability of the carrying value of its long-lived assets, primarily property and equipment. When certain events and circumstances indicate the cost of an asset or assets may be impaired, the Company recognizes a write-down to estimated fair value, which is obtained from quoted prices or expected discounted cash flows from the related assets. There were no impairment losses recognized during the three and six months ended June 30, 2014 and 2013.

 

Concentration of Credit Risk

 

Substantially all accounts receivable result from uncollateralized natural gas and oil sales or working interest billings to third parties in the oil and gas industry. This concentration of customers may impact overall credit risk, as these entities may be similarly affected by changes in economic and other conditions. The Company maintains its cash and cash equivalents in a commercial bank. Management does not believe a significant credit risk exists at June 30, 2014 and December 31, 2013.

 

Use of Estimates

 

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Material estimates that are particularly susceptible to significant change in the near term include the determination of depreciation, depletion, and amortization, asset retirement obligations, and the valuation of oil and gas properties.

 

The Company’s oil and gas reserve quantities are the basis for the calculation of depreciation, depletion, and amortization, and impairment of oil and gas properties. Inputs for the Company’s reserve estimates are determined internally. Management emphasizes that reserve estimates are inherently imprecise and that estimates of reserves of non-producing properties and more recent discoveries are more imprecise than those for properties with long production histories.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies (Continued)

 

Use of Estimates (Continued)

 

In addition to the uncertainties inherent in the reserve estimation process, these amounts are affected by historical and projected prices for oil and natural gas which have typically been volatile. It is reasonably possible that the Company’s oil and gas reserve estimates may materially change in subsequent years.

 

Income Taxes

 

The Company is treated as a partnership for income tax purposes and, as such, the members are taxed separately on their distributive share of the Company’s income, whether or not that income is actually distributed.

 

The Company follows the guidance of the Income Taxes Topic of FASB ASC 740. ASC 740 prescribes a recognition threshold and measurement attribute for financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return, and also provides guidance on various related matters such as derecognition, interest, penalties, and disclosures required. The Company recognizes interest and penalties, if any, related to unrecognized tax benefits in income tax expense.

 

As stated above, taxable income or loss of the Company is included in the tax returns of its members. The Company files a U.S. federal income tax return, and a state franchise tax return in Texas. Returns filed in these jurisdictions for tax years ended on or after December 31, 2010 are subject to examination by the relevant taxing authorities. The Company is not currently under examination by any taxing authority.

 

The Company’s management has determined that there were no uncertain tax positions as of June 30, 2014 and December 31, 2013.

 

Note 2. Significant Customers

 

During the three and six months ended June 30, 2014, two customers made up approximately 91% of the Company’s revenue and 92% of accounts receivable.

 

During the three and six months ended June 30, 2013, one customer made up approximately 92% of the Company’s revenue and 85% of accounts receivable.

 

Note 3. Unproved Properties

 

The Company is currently participating in oil and gas exploration and development activities. Unproved property costs and exploration costs have been excluded in computing amortization of the full cost pool, as a determination cannot be made about the extent of additional oil reserves that should be classified as proved reserves as a result of these projects. The cost of unproved leases which become productive is reclassified to proved properties when proved reserves are discovered on the property. Unproved oil and gas interests are carried at the lower of cost or estimated fair market value.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 3. Unproved Properties (Continued)

 

The following table reflects the net changes in unproved property costs:

 

     June 30,
2014
    December 31,
2013
 

Beginning Balance

   $ 410,217      $ 9,918,310   

Additions to Capitalized Property Costs Pending the Determination of Proved Reserves

     27,526,272        410,217   

Reclassifications to Properties Being Amortized Based on the Determination of Proved Reserves

     (9,835,416     (9,918,310
  

 

 

   

 

 

 

Ending Balance

   $ 18,101,073      $ 410,217   
  

 

 

   

 

 

 

 

The Company has approximately $410,217 of unproved property costs remaining from 2013 included in the balance as of June 30, 2014. The Company expects to complete its evaluation of these costs in 2014.

 

Note 4. Acquisitions of Oil and Gas Properties

 

The Company follows the guidance of FASB ASC 805, Business Combinations, when accounting for acquisition costs incurred on the purchase of a working interest in oil and gas properties. As such, acquisition costs are expensed as incurred. Acquisition expenses totaled $83,700, $784,384, $190,861, and $1,717,193, for the three and six months ended June 30, 2014 and 2013, respectively.

 

Note 5. Notes Payable

 

Notes payable at June 30, 2014 and December 31, 2013, consisted of the following:

 

     June 30,
2014
     December 31,
2013
 

Revolving Loan Agreement for up to $100,000,000, interest at LIBOR (2.53% average rate at June 30, 2014), principal due at maturity February 5, 2017, periodic interest payments, secured by all of the Company’s current and future oil and gas properties and interests, and all derivative instruments.

   $ 19,000,000       $ 23,400,000   
  

 

 

    

 

 

 

Total

   $ 19,000,000       $ 23,400,000   
  

 

 

    

 

 

 

 

Maturities are as follows as of June 30, 2014:

 

     

2017

   $ 19,000,000      
  

 

 

    

 

Interest expense, including loan origination fees, for the three and six months ended June 30, 2014 and 2013, totaled $129,712, $191,437, $316,634, and $287,212, respectively.

 

The Company is subject to certain restrictive financial covenants under the credit facility, including a positive working capital requirement of greater than or equal to 1.0 to 1.0, and a Debt to EBITDAX ratio less than or equal to 4.0 to 1.0, all as defined in the Credit Agreement. The credit facility also includes customary restrictions with respect to liens, indebtedness, loans and investments, material changes in the Company’s business, asset sales or leases or transfers of assets, restricted payments, such as distributions and dividends, mergers or consolidations, and transactions with affiliates. At June 30, 2014, the Company was in compliance with the covenants.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 6. Fair Value Measurement

 

The Company values its financial instruments as required by FASB ASC 825. The carrying amounts of cash, receivables, commodity derivative instruments, and notes payable approximate fair value. The Company estimates the fair value of its notes payable generally using discounted cash flow analysis based on the Company’s current borrowing rates for similar types of debt. The carrying amounts of the Company’s financial instruments generally approximate their fair values at June 30, 2014 and December 31, 2013.

 

FASB ASC 820, among other matters, establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value.

 

The three levels of the fair value hierarchy are described below:

 

Level 1—Quoted prices are available in active markets for identical investments as of the reporting date. The types of investments in Level 1 include listed equity and debt securities.

 

Level 2—Pricing inputs are other than quoted prices in active markets, which are either directly or indirectly observable as of the reporting date, and fair value is determined through the use of models or other valuation methodologies. Investments which are generally included in this category include less liquid and restricted equity securities and over-the-counter derivatives.

 

Level 3—Pricing inputs are unobservable for the investment and include situations where there is little, if any, market activity for the investment. The inputs into the determination of fair value require significant management judgment or estimation. Investments that are included in this category generally include general and limited partnership interests in corporate private equity funds and funds of hedge funds.

 

In some instances, the inputs used to measure fair value may fall into different levels of the fair value hierarchy. In such instances, an investment’s level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement.

 

The preceding methods described may produce a fair value calculation that may not be indicative of the net realizable value or reflective of future fair values. Furthermore, although the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date. There have been no changes in the methodologies used during the periods presented.

 

The valuation of the Company’s assets measured on a recurring basis by the above fair value hierarchy at June 30, 2014 and December 31, 2013, is as follows:

 

     June 30, 2014  
     Total      Level 1      Level 2      Level 3  

Assets

           

Commodity Derivative Instruments

   $ 6,360       $ —         $ 6,360       $ —     
  

 

 

    

 

 

    

 

 

    

 

 

 

Liabilities

           

Commodity Derivative Instruments

   $ 9,724,785       $ —         $ 9,724,785       $ —     
  

 

 

    

 

 

    

 

 

    

 

 

 

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 6. Fair Value Measurement (Continued)

 

     December 31, 2013  
     Total      Level 1      Level 2      Level 3  

Assets

   $ —         $ —         $ —         $ —     
  

 

 

    

 

 

    

 

 

    

 

 

 

Liabilities

           

Commodity Derivative Instruments

   $ 3,443,968       $ —         $ 3,443,968       $ —     
  

 

 

    

 

 

    

 

 

    

 

 

 

 

Note 7. Commodity Derivative Instruments

 

The cash settlements of commodity derivative instruments are recorded into revenue. Outstanding instruments not qualifying for hedge accounting treatment are recorded on the balance sheet at fair value, and changes in fair value are recognized in earnings as unrealized gains or losses. As the result of instruments settled, the Company recognized net derivative losses of $3,188,631, $14,904, $4,045,771, and $14,904, respectively, during the three and six month periods ended June 30, 2014 and 2013. In addition, the Company recognized unrealized net derivative (losses) gains of ($4,944,285), $898,513, ($6,274,457), and ($42,350), respectively, during the three and six month periods ended June 30, 2014 and 2013.

 

As of June 30, 2014, the Company had the following oil and gas derivative contracts still in place:

 

      June 30, 2014  

Production Period

   Instrument
Type
     Volume      Price  

Crude Oil:

        

2014

     Swap         54,000 Bbls       $ 89.80   

2014

     Swap         276,000 Bbls       $ 90.50   

2014

     Swap         210,000 Bbls       $ 95.80   

2015

     Swap         456,000 Bbls       $ 88.20   

Natural Gas:

        

2014

     Swap         120,000 Mmbtu       $ 4.19   

2014

     Swap         36,000 Mmbtu       $ 4.46   

 

At June 30, 2014 and December 31, 2013, the Company recognized gross assets of $6,360 and $-0-, respectively, and gross liabilities of $9,724,785 and $3,443,968, respectively, related to the estimated fair value of these derivative instruments. Derivatives expected to settle for gains in the next twelve months totaled $6,360 and $-0-, at June 30, 2014 and December 31, 2013, respectively. Derivatives expected to settle for losses in the next twelve months totaled $8,166,094 and $3,443,968, at June 30, 2014 and December 31, 2013, respectively. All of the Company’s commodity derivative instruments expire by December 31, 2015.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 8. Asset Retirement Obligations

 

The Company accounts for plugging and abandonment costs in accordance with FASB ASC 410.

 

A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations is as follows:

 

     June 30,
2014
     December 31,
2013
 

Beginning Balance

   $ 4,265,600       $ 3,340,403   

Liabilities Incurred

     125,003         1,458,518   

Liabilities Settled

     —           —     

Liabilities Associated with Sales of Properties

     —           —     

Accretion Expense

     63,698         97,883   

Revisions

     —           (631,204
  

 

 

    

 

 

 

Estimated Ending Balance

   $ 4,454,301       $ 4,265,600   
  

 

 

    

 

 

 

 

In the course of its normal business affairs, the Company is subject to possible loss contingencies arising from federal, state, and local environmental, health, and safety laws and regulations and third-party litigation. There are no matters which, in the opinion of management, will have a material adverse effect on the financial position, results of operations, or cash flows of the Company.

 

The Company leases office space from unrelated parties. Future payments required on the lease agreements as of June 30, 2014, are as follows:

 

     Amount  

2014

   $ 76,028   

2015

     257,103   

2016

     257,103   

2017

     257,103   

2018

     257,103   

Thereafter

     214,254   
  

 

 

 

Total

   $ 1,318,694   
  

 

 

 

 

Note 10. Members’ Equity

 

In connection with the formation of the Company, Kayne Anderson Energy Fund V, L.P., Kayne Anderson Energy Fund V QP, L.P. (collectively Kayne) and Treadstone Energy Partners Management, LLC (Management) entered into a limited liability company agreement and unit purchase agreement dated March 1, 2011. Pursuant to these agreements, the Company may issue an aggregate of 49,250 Series A and 750 Series B common membership units at $1,000 per unit to Kayne and Management, respectively.

 

Upon request, members are required to make pro-rata capital contributions to the Company based on the respective contribution percentage of each member. Net income (loss) is allocated to the members in accordance with the LLC agreement, as appropriate. Amounts distributed to each member shall be allocated and distributed in accordance with the applicable sharing percentages per the LLC agreement based on a structured payout schedule. As of June 30, 2014 and December 31, 2013, there have been no distributions made to members.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 11. Employee Benefit Plan

 

The Company maintains a 401(k) profit sharing plan which covers all employees over the age of 21. Employees are eligible to participate following a three month waiting period. The employer match is 3% under the safe harbor plan. The Company may also make a discretionary profit sharing contribution to the plan. The Company made contributions totaling $10,606, $8,700, $21,031, and $17,263, respectively, for the three and six months ended June 30, 2014 and 2013.

 

Note 12. Subsequent Events

 

Management has evaluated subsequent events through August 26, 2014, the date these financial statements were available to be issued. No events have occurred that would have a material effect on the financial statements as of that date except as disclosed below.

 

On July 22, 2014, the Company completed the sale of its Ft. Trinidad properties to Energy & Exploration Partners, Inc. This transaction was effective as of April 1, 2014 and included approximately 18,300 net acres of oil and gas leasehold in Houston and Madison Counties, Texas, and thirty-six net producing wells for a cash purchase price of $715 million, subject to customary purchase price adjustments. The Company repaid all outstanding notes payable and all commodity derivative instruments were settled. The Company is in the process of determining the gain as a result of this transaction.

 

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LOGO   

LaPorte, APAC

5100 Village Walk | Suite 300

Covington, LA 70433

985.892.5850 | Fax 985.892.5956

LaPorte.com

 

INDEPENDENT AUDITOR’S REPORT

 

To the Members

Treadstone Energy Partners, LLC

 

Report on the Financial Statements

 

We have audited the accompanying financial statements of Treadstone Energy Partners, LLC (the Company) which comprise the balance sheets as of December 31, 2013 and 2012, and the related statements of operations, changes in members’ capital, and cash flows for the years then ended, and the related notes to the financial statements.

 

Management’s Responsibility for the Financial Statements

 

Management is responsible for the preparation and fair presentation of these financial statements in accordance with accounting principles generally accepted in the United States of America; this includes the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error.

 

Auditor’s Responsibility

 

Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement.

 

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the financial statements. The procedures selected depend on the auditor’s judgment, including the assessment of the risks of material misstatement of the financial statements, whether due to fraud or error. In making those risk assessments, the auditor considers internal control relevant to the entity’s preparation and fair presentation of the financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control. Accordingly, we express no such opinion. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluating the overall presentation of the financial statements.

 

We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.

 

LOGO

 

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Opinion

 

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Treadstone Energy Partners, LLC as of December 31, 2013 and 2012, and the results of its operations and its cash flows for the years then ended, in accordance with accounting principles generally accepted in the United States of America.

 

LOGO

 

A Professional Accounting Corporation

 

Covington, LA

March 19, 2014

 

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TREADSTONE ENERGY PARTNERS, LLC

 

BALANCE SHEETS

DECEMBER 31, 2013 AND 2012

 

     2012     2013  

Assets

    

Current Assets

    

Cash and Cash Equivalents

   $ 5,699,837      $ 6,845,661   

Oil and Gas Sales Receivable

     4,755,082        14,599,245   

Accounts Receivable

     97,791        610,521   

Prepaid Expenses and Other Current Assets

     397,717        154,737   
  

 

 

   

 

 

 

Total Current Assets

     10,950,427        22,210,164   
  

 

 

   

 

 

 

Property and Equipment

    

Full Cost Used for Oil and Gas Properties:

    

Proved Properties Being Amortized

     38,720,051        139,656,920   

Unproved Properties Not Subject to Amortization

     9,918,310        410,217   

Other Property and Equipment

     73,649        73,649   
  

 

 

   

 

 

 
     48,712,010        140,140,786   

Less: Accumulated Depreciation, Depletion, and Amortization

     (5,403,864     (21,534,715
  

 

 

   

 

 

 

Total Property and Equipment, Net

     43,308,146        118,606,071   
  

 

 

   

 

 

 

Other Assets

    

Deposits

     30,345        8,136   
  

 

 

   

 

 

 

Total Other Assets

     30,345        8,136   
  

 

 

   

 

 

 

Total Assets

   $ 54,288,918      $ 140,824,371   
  

 

 

   

 

 

 

Liabilities and Members’ Capital

    

Current Liabilities

    

Accounts Payable and Accrued Expenses

   $ 5,685,253      $ 11,162,543   

Revenue and Royalties Payable

     1,576,933        7,538,126   

Commodity Derivative Instruments at Fair Value

     —          3,443,968   
  

 

 

   

 

 

 

Total Current Liabilities

     7,262,186        22,144,637   
  

 

 

   

 

 

 

Long-Term Liabilities

    

Notes Payable

     —          23,400,000   

Asset Retirement Obligations

     3,340,403        4,265,600   
  

 

 

   

 

 

 

Total Long-Term Liabilities

     3,340,403        27,665,600   
  

 

 

   

 

 

 

Total Liabilities

     10,602,589        49,810,237   
  

 

 

   

 

 

 

Members’ Capital

     43,686,329        91,014,134   
  

 

 

   

 

 

 

Total Liabilities and Members’ Capital

   $ 54,288,918      $ 140,824,371   
  

 

 

   

 

 

 

 

The accompanying notes are an integral part of these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

STATEMENTS OF OPERATIONS

FOR THE YEARS ENDED DECEMBER 31, 2013 AND 2012

 

     2012      2013  

Revenue

     

Oil and Gas Revenue, Net of Royalties

   $ 14,477,992       $ 86,392,442   

Realized Losses on Commodity Derivative Instruments

     —           (2,542,662
  

 

 

    

 

 

 

Total Revenue

     14,477,992         83,849,780   
  

 

 

    

 

 

 

Operating Expenses

     

Lease Operating Expenses

     1,769,074         8,317,074   

Depreciation, Depletion, and Amortization

     5,380,620         16,130,852   

Production Taxes

     658,027         4,126,417   

Acquisition Expenses

     1,548,893         1,066,178   

Accretion Expenses

     5,054         97,883   

General and Administrative

     2,452,838         2,742,830   
  

 

 

    

 

 

 

Total Operating Expenses

     11,814,506         32,481,234   
  

 

 

    

 

 

 

Operating Income

     2,663,486         51,368,546   
  

 

 

    

 

 

 

Other Income (Expense)

     

Interest Expense

     —           (596,773

Unrealized Losses on Commodity Derivative Instruments

     —           (3,443,968
  

 

 

    

 

 

 

Total Other Income (Expense)

     —           (4,040,741
  

 

 

    

 

 

 

Net Income

   $ 2,663,486       $ 47,327,805   
  

 

 

    

 

 

 

 

 

The accompanying notes are an integral part of these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

STATEMENTS OF CHANGES IN MEMBERS’ CAPITAL

FOR THE YEARS ENDED DECEMBER 31, 2013 AND 2012

 

     Series A
Units
     Series B
Units
     Member
Contributions
     Retained
Earnings
    Total  

Balance, December 31, 2011

     8,620         130       $ 8,650,000       $ (1,427,157   $ 7,222,843   

Net Income

     —           —           —           2,663,486        2,663,486   

Contributions from Members

     33,293         507         33,800,000         —          33,800,000   
  

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Balance, December 31, 2012

     41,913         637         42,450,000         1,236,329        43,686,329   

Net Income

     —           —           —           47,327,805        47,327,805   

Contributions from Members

     —           —           —           —          —     
  

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

Balance, December 31, 2013

     41,913         637       $ 42,450,000       $ 48,564,134      $ 91,014,134   
  

 

 

    

 

 

    

 

 

    

 

 

   

 

 

 

 

The accompanying notes are an integral part of these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, 2013 AND 2012

 

     2012     2013  

Cash Flows from Operating Activities

    

Net Income

   $ 2,663,486      $ 47,327,805   

Adjustments to Reconcile Net lncome to Net Cash
Provided by Operating Activities

    

Depreciation, Depletion, and Amortization

     5,380,620        16,130,852   

Accretion Expense

     5,054        97,883   

Unrealized Losses on Commodity Derivative Instruments

     —          3,443,968   

Increase in Oil and Gas Sales Receivable

     (4,666,110     (9,844,163

(Increase) Decrease in Accounts Receivable

     32,501        (512,730

Decrease in Prepaid Expenses and Other Current Assets

     483,290        242,979   

Increase in Accounts Payable and Accrued Expenses

     4,864,050        5,477,290   

Increase in Revenue and Royalties Payable

     1,527,453        5,961,193   
  

 

 

   

 

 

 

Net Cash Provided by Operating Activities

     10,290,344        68,325,077   
  

 

 

   

 

 

 

Cash Flows from Investing Activities

    

Acquisition and Development of Oil and Gas Properties

     (40,184,418     (90,601,462

Decrease in Deposits

     797,390        22,209   
  

 

 

   

 

 

 

Net Cash Used in Investing Activities

     (39,387,028     (90,579,253
  

 

 

   

 

 

 

Cash Flows from Financing Activities

    

Proceeds from Notes Payable

     —          27,000,000   

Repayments on Notes Payable

     —          (3,600,000

Member Contributions

     33,800,000        —     
  

 

 

   

 

 

 

Net Cash Provided by Financing Activities

     33,800,000        23,400,000   
  

 

 

   

 

 

 

Net Increase in Cash and Cash Equivalents

     4,703,316        1,145,824   

Cash and Cash Equivalents, Beginning

     996,521        5,699,837   
  

 

 

   

 

 

 

Cash and Cash Equivalents, Ending

   $ 5,699,837      $ 6,845,661   
  

 

 

   

 

 

 

Supplemental Disclosures of Cash Flow Information

    

Interest Paid

   $ —        $ 503,773   

Non Cash Asset Retirement Obligations Capitalized

     3,194,524        827,314   

Non Cash Accruals for Capital Expenditures

     423,226        1,000,000   

 

The accompanying notes are an integral part of these financial statements.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies

 

Treadstone Energy Partners, LLC (the Company), is an independent oil and gas company engaged primarily in the acquisition, exploration, development, and production of crude oil and natural gas in the State of Texas. The Company was formed as a Delaware limited liability company on February 24, 2011.

 

Basis of Presentation

 

The accompanying financial statements have been prepared on the accrual basis of accounting in accordance with accounting principles generally accepted in the United States of America (GAAP).

 

Cash and Cash Equivalents

 

For the purpose of the statement of cash flows, the Company considers all highly liquid investments with a maturity of three months or less to be cash equivalents. As of December 31, 2013 and 2012, the Company did not have any short-term investments classified as cash equivalents.

 

Accounts Receivable

 

Accounts receivable consist of uncollateralized oil and natural gas revenues due under normal trade terms, as well as amounts due from working interest owners of oil and gas properties for their share of expenses paid on their behalf by the Company. Management reviews receivables periodically and reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount that may not be collectible. As of December 31, 2013 and 2012, the valuation allowance was $-0-.

 

Oil and Gas Producing Activities

 

The Company follows the full cost method of accounting for oil and gas properties. Under the full cost method, all costs associated with property acquisition, exploration, and development activities are capitalized. Capitalized costs include lease acquisitions, geological and geophysical work, delay rentals, costs of drilling, completing and equipping successful and unsuccessful oil and gas wells, and directly related costs.

 

Once evaluated, all capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves and the estimated cost of dismantlement and abandonment, net of salvage value, are amortized on the units-of-production method using estimates of proved reserves. Investments in unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized.

 

Costs associated with unproved properties and properties under development are excluded from the full cost amortization base until the properties have been evaluated. Unproved properties are transferred into the full cost pool subject to amortization when management determines that a field has been evaluated through drilling operations or a thorough geologic evaluation.

 

In addition, the capitalized costs are subject to a “ceiling test”, which basically limits such costs to the aggregate of the “estimated present value”, discounted at a ten percent (10%) interest rate of future net revenues from proved reserves, based on current economic and operating conditions, plus the lower of cost or fair market value of unproved properties.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies (Continued)

 

Oil and Gas Producing Activities (Continued)

 

Sales of proved and unproved properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. Abandonment of properties is accounted for as adjustments of capitalized costs with no loss recognized.

 

The Company follows the guidance of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) No. 2010-03, Extractive Activities—Oil and Gas (Topic) 932. This ASU provides estimation and disclosure requirements for oil and gas reserves, designed to align them with the requirements of the Securities and Exchange Commission (SEC). The guidance, among other purposes, is primarily intended to provide investors with a more meaningful and comprehensive understanding of oil and gas producing activities, updating the definition of proved oil and gas reserves to indicate that entities must use the average, first-day-of-the-month price during the 12-month period before the ending date of the period covered by the report, disclosing geographical areas that represent a certain percentage of proved reserves, updating the reserve estimation requirements for changes in practice and technology that have occurred over the past several decades, and requiring an entity to disclose separately the amounts and quantities for consolidated and equity method investments. The Company has applied this guidance to its financial statements for the years ended December 31, 2013 and 2012.

 

Depreciation, depletion, and amortization (DD&A) is computed on the units-of-production method. DD&A expense includes the amounts computed on capitalized future plugging and abandonment costs. Depreciation, depletion, and amortization expense for the Company’s oil and gas properties totaled $16,118,049 and $5,368,202, for the years ended December 31, 2013 and 2012, respectively.

 

Other Property and Equipment

 

Other property and equipment, which includes office furniture and equipment, is depreciated using the straight-line method over the estimated useful lives of the assets ranging from three to ten years. Gain or loss on retirement, sale, or other disposition of these assets is included in income in the period of disposition. Costs of major repairs that extend the useful life are capitalized. Costs for maintenance and repairs are expensed as incurred. Depreciation expense for other property and equipment totaled $12,803 and $12,418, for the years ended December 31, 2013 and 2012, respectively.

 

Revenue Recognition

 

The Company recognizes oil and gas revenue from its interests in producing wells using the sales method. Under this method, revenues are recognized based on actual volumes of oil and gas produced and delivered to purchasers. As a result, the Company accrues revenue relating to production for which the Company has not yet received payment.

 

Hedging Agreements

 

The Company manages the potential impact of changes in the price of oil and natural gas by entering into derivative commodity instruments (hedges), but does not use them for speculative purposes.

 

The Company accounts for hedging agreements in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 815. ASC 815 requires the Company to recognize all

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies (Continued)

 

Hedging Agreements (Continued)

 

derivative instruments on the balance sheet as either an asset or liability, measured at fair value, and requires that changes in a derivative’s fair value be realized currently in earnings, unless hedge accounting criteria are met.

 

The Company’s hedges are specifically referenced to the NYMEX index prices received for its designated production. Estimating the fair value of derivatives requires complex calculations incorporating estimates of future prices, discount rates, and price movements. As a result, the Company obtains the fair value of its commodity derivatives from the counterparties to those contracts. Because the counterparties are market makers, they are able to provide a literal market value, or what they would be willing to settle such contracts for as of the given date.

 

Asset Retirement Obligations

 

The Company accounts for future plugging and abandonment costs in accordance with FASB ASC 410. ASC 410 requires legal obligations associated with the retirement of long-lived assets (i.e., future plugging and abandonment costs) to be recognized at their fair value at the time the obligations are incurred. Upon initial recognition of the liability, that cost is capitalized as part of the carrying amount of the related long-lived asset. The estimate of future plugging and abandonment costs is highly subjective. Management’s current estimate of the Company’s share of such future costs is approximately $4,265,600 and $3,340,403, as of December 31, 2013 and 2012, respectively.

 

Long-Lived Assets

 

The Company continually evaluates the recoverability of the carrying value of its long-lived assets, primarily property and equipment. When certain events and circumstances indicate the cost of an asset or assets may be impaired, the Company recognizes a write-down to estimated fair value, which is obtained from quoted prices or expected discounted cash flows from the related assets. There were no impairment losses recognized during the years ended December 31, 2013 and 2012.

 

Concentration of Credit Risk

 

Substantially all accounts receivable result from uncollateralized natural gas and oil sales or joint interest billings to third parties in the oil and gas industry. This concentration of customers may impact overall credit risk, as these entities may be similarly affected by changes in economic and other conditions. The Company maintains its cash and cash equivalents in a commercial bank. Management does not believe a significant credit risks exist at December 31, 2013 and 2012.

 

Income Taxes

 

The Company is treated as a partnership for income tax purposes and, as such, the members are taxed separately on their distributive share of the Company’s income, whether or not that income is actually distributed.

 

The Company follows the guidance of the Income Taxes Topic of FASB ASC 740. ASC 740 prescribes a recognition threshold and measurement attribute for financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return, and also provides guidance on various related matters such as derecognition, interest, penalties, and disclosures required. The Company recognizes interest and penalties, if any, related to unrecognized tax benefits in income tax expense.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 1. Summary of Significant Accounting Policies (Continued)

 

Income Taxes (Continued)

 

As stated above, taxable income or loss of the Company is included in the tax returns of its members. The Company files a U.S. federal income tax return, and a state franchise tax return in Texas. Returns filed in these jurisdictions for tax years ended on or after December 31, 2011 are subject to examination by the relevant taxing authorities. The Company is not currently under examination by any taxing authority.

 

The Company’s management has determined that there were no uncertain tax positions as of December 31, 2013 and 2012.

 

Use of Estimates

 

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Material estimates that are particularly susceptible to significant change in the near term include the determination of depreciation, depletion, and amortization, asset retirement obligations, and the valuation of oil and gas properties.

 

The Company’s oil and gas reserve quantities are the basis for the calculation of depreciation, depletion, and amortization, and impairment of oil and gas properties. Inputs for the Company’s reserve estimates are determined internally. Management emphasizes that reserve estimates are inherently imprecise and that estimates of reserves of non-producing properties and more recent discoveries are more imprecise than those for properties with long production histories.

 

In addition to the uncertainties inherent in the reserve estimation process, these amounts are affected by historical and projected prices for oil and natural gas which have typically been volatile. It is reasonably possible that the Company’s oil and gas reserve estimates may materially change in subsequent years.

 

Reclassifications

 

Certain previously presented amounts have been reclassified to conform to the current financial statement presentation.

 

Note 2. Significant Customers

 

During the year ended December 31, 2013, one customer made up 92% of the Company’s revenue and 86% of accounts receivable.

 

During the year ended December 31, 2012, one customer made up 93% of the Company’s revenue and 93% of accounts receivable.

 

Note 3. Unproved Properties

 

The Company is currently participating in oil and gas exploration and development activities. Unproved property costs and exploration costs have been excluded in computing amortization of the full cost pool, as a determination cannot be made about the extent of additional oil reserves that should be classified as proved reserves as a result of these projects. The cost of unproved leases which become productive is reclassified to

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 3. Unproved Properties (Continued)

 

proved properties when proved reserves are discovered on the property. Unproved oil and gas interests are carried at the lower of cost or estimated fair market value.

 

The following table reflects the net changes in unproved property costs during the years ended December 31, 2013 and 2012:

 

     2012     2013  

Beginning Balance

   $ 5,352,287      $ 9,918,310   

Additions to Capitalized Property Costs Pending the Determination of Proved Reserves

     6,901,412        410,217   

Reclassifications to Properties Being Amortized Based on the Determination of Proved Reserves

     (2,335,389     (9,918,310
  

 

 

   

 

 

 

Ending Balance

   $ 9,918,310      $ 410,217   
  

 

 

   

 

 

 

 

The Company has approximately $401,217 of unproved property costs remaining from 2012 included in the balance as of December 31, 2013. The Company expects to complete its evaluation of these costs in 2014.

 

Note 4. Acquisitions of Oil and Gas Properties

 

In February 2013, the Company acquired oil and gas properties totaling approximately $4,398,600. In October 2012, the Company acquired certain oil and gas properties for total cash consideration of $16,629,567, which was based on the contract acquisition price of $17,900,000, net of revenues, expenses, and certain other purchase price adjustments agreed to with the seller from the effective date through the closing date.

 

The Company follows the guidance of FASB ASC 805, Business Combinations, when accounting for acquisition costs incurred on the purchase of a working interest in oil and gas properties. As such, acquisition costs are expensed as incurred. Acquisition expenses from the above transactions totaled $1,066,178 and $1,548,893, for the years ended December 31, 2013 and 2012, respectively.

 

Note 5. Notes Payable

 

Notes payable at December 31, 2013 and 2012, consisted of the following:

 

     2012      2013  

Revolving Loan Agreement for up to $100,000,000, interest at LIBOR (2.73% average rate at December 31, 2013), principal due at maturity February 5, 2017, periodic interest payments, secured by all of the Company’s current and future oil and gas properties and interests, and all hedging instruments.

   $ —         $ 23,400,000   
  

 

 

    

 

 

 

Total

   $ —         $ 23,400,000   
  

 

 

    

 

 

 

 

Maturities are as follows for the twelve months ended December 31st:

 

2017

   $ 23,400,000   
  

 

 

 

 

Interest expense, including loan origination fees, for the years ended December 31, 2013 and 2012, totaled $596,773 and $-0-, respectively.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 5. Notes Payable (Continued)

 

The Company is subject to certain restrictive financial covenants under the credit facility, including a positive working capital requirement of greater than or equal to 1.0 to 1.0, and a Debt to EBITDAX ratio less than or equal to 4.0 to 1.0, all as defined in the Credit Agreement. The credit facility also includes customary restrictions with respect to liens, indebtedness, loans and investments, material changes in the Company’s business, asset sales or leases or transfers of assets, restricted payments, such as distributions and dividends, mergers or consolidations, and transactions with affiliates. At December 31, 2013, the Company was in compliance with the covenants.

 

Note 6. Fair Value of Financial Instruments

 

The Company values its financial instruments as required by FASB ASC 825. The carrying amounts of cash, receivables, commodity derivative instruments, and notes payable approximate fair value. The Company estimates the fair value of its notes payable generally using discounted cash flow analysis based on the Company’s current borrowing rates for similar types of debt. The carrying amounts of the Company’s financial instruments generally approximate their fair values at December 31, 2013 and 2012.

 

FASB ASC 820, among other matters, establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value.

 

The three levels of the fair value hierarchy are described below:

 

Level 1—Quoted prices are available in active markets for identical investments as of the reporting date. The types of investments in Level 1 include listed equity and debt securities.

 

Level 2—Pricing inputs are other than quoted prices in active markets, which are either directly or indirectly observable as of the reporting date, and fair value is determined through the use of models or other valuation methodologies. Investments which are generally included in this category include less liquid and restricted equity securities and over-the-counter derivatives.

 

Level 3—Pricing inputs are unobservable for the investment and include situations where there is little, if any, market activity for the investment. The inputs into the determination of fair value require significant management judgment or estimation. Investments that are included in this category generally include general and limited partnership interests in corporate private equity funds, and funds of hedge funds.

 

In some instances, the inputs used to measure fair value may fall into different levels of the fair value hierarchy. In such instances, an investment’s level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement.

 

The preceding methods described may produce a fair value calculation that may not be indicative of the net realizable value or reflective of future fair values. Furthermore, although the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date. There have been no changes in the methodologies used during the years ended December 31, 2013 and 2012.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 6. Fair Value of Financial Instruments (Continued)

 

The valuation of the Company’s assets measured on a recurring basis by the above fair value hierarchy at December 31, 2013, is as follows:

 

     Total      Level 1      Level 2      Level 3  

Assets

   $ —         $ —         $ —         $ —     
  

 

 

    

 

 

    

 

 

    

 

 

 

Liabilities

           

Commodity Derivative Instruments

   $ 3,443,968       $ —         $ 3,443,968       $ —     
  

 

 

    

 

 

    

 

 

    

 

 

 

 

The Company had no assets or liabilities measured on a recurring basis by the above fair value hierarchy at December 31, 2012.

 

Note 7. Commodity Derivative Instruments

 

The cash settlements of commodity derivative instruments are recorded into revenue. Outstanding instruments not qualifying for hedge accounting treatment are recorded on the balance sheet at fair value, and changes in fair value are recognized in earnings as unrealized gains or losses. As the result of instruments settled during the year, the Company recognized net derivative losses of $2,542,662 and $-0-, respectively, for the years ended December 31, 2013 and 2012. In addition, for the years ended December 31, 2013 and 2012, the Company recognized and $3,443,968 and $-0-, respectively, in unrealized net derivative losses.

 

As of December 31, 2013, the Company had the following oil and gas derivative contracts still in place:

 

Production Period

   Instrument
Type
     Volume      Price  

Crude Oil:

        

2014

     Swap         552,000 Bbls       $ 90.50   

2014

     Swap         108,000 Bbls       $ 89.80   

Natural Gas:

        

2014

     Swap         240,000 Mmbtu       $ 4.19   

 

At December 31, 2013, the Company recognized gross assets of $-0-, and gross liabilities of $3,443,968, related to the estimated fair value of these derivative instruments. Hedges expected to settle for gains in the next twelve months totaled $-0-, at December 31, 2013. Hedges expected to settle for losses in the next twelve months totaled $3,443,968, at December 31, 2013. All of the Company’s commodity derivative instruments expire by December 31, 2014. There were no commodity derivative instruments in place at December 31, 2012.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 8. Asset Retirement Obligations

 

The Company accounts for plugging and abandonment costs in accordance with FASB ASC 410.

 

A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations is as follows:

 

     2012     2013  

Beginning Balance

   $ 158,135      $ 3,340,403   

Liabilities Incurred

     3,194,524        1,458,518   

Liabilities Settled

     —          —     

Liabilities Associated with Sales of Properties

     (17,310     —     

Accretion Expense

     5,054        97,883   

Revisions

     —          (631,204
  

 

 

   

 

 

 

Estimated Ending Balance

   $ 3,340,403      $ 4,265,600   
  

 

 

   

 

 

 

 

Note 9. Commitments and Contingencies

 

In the course of its normal business affairs, the Company is subject to possible loss contingencies arising from federal, state, and local environmental, health, and safety laws and regulations and third-party litigation. There are no matters which, in the opinion of management, will have a material adverse effect on the financial position, results of operations, or cash flows of the Company.

 

The Company leases office space from an unrelated party. The lease expires August 31, 2014. Future payments required on the lease agreement as of December 31, 2013, are as follows:

 

December 31,

   Amount  

2014

   $ 88,472   
  

 

 

 

 

Note 10. Members’ Equity

 

In connection with the formation of the Company, Kayne Anderson Energy Fund V, L.P., Kayne Anderson Energy Fund V QP, L.P. (collectively Kayne), and Treadstone Energy Partners Management, LLC (Management) entered into a limited liability company agreement and unit purchase agreement dated March 1, 2011. Pursuant to these agreements, the Company may issue an aggregate of 49,250 Series A and 750 Series B common membership units at $1,000 per unit to Kayne and Management, respectively.

 

Upon request, members are required to make pro rata capital contributions to the Company based on the respective contribution percentage of each member. Net income (loss) is allocated to the members in accordance with the LLC agreement, as appropriate. Amounts distributed to each member shall be allocated and distributed in accordance with the applicable sharing percentages per the LLC agreement based on a structured payout schedule. As of December 31, 2013, there have been no distributions made to members.

 

Note 11. Employee Benefit Plan

 

The Company maintains a 401(k) Profit Sharing Plan which covers all employees over the age of 21. Employees are eligible to participate following a three month waiting period. The employer match is 3% under the safe harbor plan. The Company may also make a discretionary profit sharing contribution to the Plan. The Company made contributions totaling $37,363 and $29,750, for the years ended December 31, 2013 and 2012, respectively.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 12. Subsequent Events

 

Management has evaluated subsequent events through March 19, 2014, the date these financial statements were available to be issued, in accordance with FASB ASC 855, and determined that there were no material subsequent events that required recognition or additional disclosure in these financial statements.

 

Note 13. Supplemental Information (Unaudited)

 

Proved Oil and Gas Reserves

 

Proved oil and gas reserves were estimated by internal petroleum engineers. Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.

 

The reserves were based on the following assumptions:

 

   

Future revenues were based on the average first-day-of-the-month oil and gas prices. Future price changes were included only to the extent provided by existing contractual agreements.

 

   

Production and development costs were computed using year-end costs assuming no change in present economic conditions.

 

   

Future net cash flows were discounted at an annual rate of 10%.

 

Uncertainties are inherent in estimating quantities of proved reserves, including many factors beyond the Company’s control. Reserve engineering is a process of estimating subsurface accumulations of oil and gas that cannot be measured in an exact manner, and the accuracy of any reserve estimate is a function of the quality of available data and its interpretation. As a result, estimates by different engineers often vary, sometimes significantly. In addition to the physical factors, such as the results of drilling, testing, and production subsequent to the date of an estimate, economic factors, such as changes in product prices or development and production expenses, may require revision of such estimates. Accordingly, oil and gas quantities ultimately recovered will vary from reserve estimates. These estimates do not include probable or possible reserves. The information provided does not represent management’s estimate of its expected future cash flows or value of proved oil and gas reserves.

 

All of the Company’s reserves are located in the United States.

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 13. Supplemental Information (Unaudited) (Continued)

 

Proved Oil and Gas Reserves (Continued)

 

The following summarizes the Company’s estimated total proved reserves at December 31, 2013 and 2012:

 

     Oil
(MBBLS)
    Gas
(MMCF)
    NGL
(MBBLS)
    MBOE  

Estimated at December 31, 2011

     30        73        —          42   

Revisions of Previous Estimates

     21        270          66   

Purchases of Reserves

     46        926        —          200   

Discoveries and Extensions(1)

     1,541        2,830        —          2,013   

Production

     (132     (222     —          (169
  

 

 

   

 

 

   

 

 

   

 

 

 

Estimated at December 31, 2012

     1,506        3,877        —          2,152   

Revisions of Previous Estimates

     1,686        373        —          1,748   

Purchases of Reserves

     —          —          —          —     

Discoveries and Extensions(1)

     17,205        16,094        2,754        22,642   

Production

     (792     (1,194     (89     (1,080
  

 

 

   

 

 

   

 

 

   

 

 

 

Estimated at December 31, 2013

     19,605        19,150        2,665        25,462   
  

 

 

   

 

 

   

 

 

   

 

 

 

 

(1)   Discoveries and extensions during the years ended December 31, 2012 and 2013 were primarily the result of applying hydraulic fracturing technology to recomplete four gross wells during 2012 and drill/recomplete twenty-four gross wells during 2013.

 

      Oil
(MBBLS)
     Gas
(MMCF)
     NGL
(MBBLS)
     MBOE  

Proved Developed Reserves:

           

December 31, 2012

     787         2,438         —           1,193   

December 31,2013

     3,909         5,309         670         5,464   

Proved Undeveloped Reserves:

           

December 31, 2012

     719         1,439         —           959   

December 31, 2013

     15,696         13,841         1,995         19,998   

 

At December 31, 2013, the date of the most recent reserve report, the approximate undiscounted and discounted (using a discount rate of 10%) future net cash flows before income taxes related to the Company’s proved oil and gas reserves were $1,459,372,000 and $858,350,000, respectively.

 

Capitalized Costs Relating to Oil and Gas Producing Activities

 

The following is a summary of capitalized costs at December 31, 2013 and 2012:

 

     2012     2013  

Proved Properties

   $ 38,720,051      $ 139,656,920   

Unproved Properties

     9,918,310        410,217   
  

 

 

   

 

 

 
     48,638,361        140,067,137   

Accumulated Depreciation, Depletion and Amortization

     (5,384,120     (21,502,169
  

 

 

   

 

 

 

Net Capitalized Costs

   $ 43,254,241      $ 118,564,968   
  

 

 

   

 

 

 

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 13. Supplemental Information (Unaudited) (Continued)

 

Costs Incurred in Oil and Gas Producing Activities

 

Following is a summary of costs incurred in oil and gas property acquisition, exploration, and development activities for 2013 and 2012:

 

     2012      2013  

Acquisitions

   $ 19,576,546       $ 4,507,491   

Exploration

     —           —     

Development

     19,793,171         86,111,085   
  

 

 

    

 

 

 

Costs Incurred

   $ 39,369,717       $ 90,618,576   
  

 

 

    

 

 

 

 

Standardized Measure of Discounted Future Net Cash Flows Relating to Reserves

 

The following information has been developed utilizing procedures prescribed by FASB ASC 932. It may be useful for certain comparative purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of the Company.

 

Under the Standardized Measure, future cash inflows were estimated by applying the 12-month average pricing of oil and gas relating to the Company’s proved reserves to the year-end quantities of those reserves. Future development and production costs represent the estimated future expenditures (based on year-end costs) to be incurred in developing and producing the proved reserves, assuming continuation of existing economic conditions. In addition, asset retirement obligation are included with future production and development costs. There are no future income tax expenses because the Company is a non-taxable entity.

 

The following is a summary of the standardized measure of discounted future net cash flows as of December 31, 2013 and 2012:

 

     2012     2013  
     (dollars in thousands)  

Future Cash Inflows

   $ 172,789      $ 2,200,117   

Future Production Costs

     (40,993     (435,277

Future Development Costs

     (36,014     (305,468
  

 

 

   

 

 

 

Future Net Cash Flows

     95,782        1,459,372   

10% Annual Discount for Estimated

    

Timing of Cash Flows

     (23,514     (601,022
  

 

 

   

 

 

 

Standardized Measure of Discounted

    

Future Net Cash Flows

   $ 72,268      $ 858,350   
  

 

 

   

 

 

 

 

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TREADSTONE ENERGY PARTNERS, LLC

 

NOTES TO FINANCIAL STATEMENTS

 

Note 13. Supplemental Information (Unaudited) (Continued)

 

Standardized Measure of Discounted Future Net Cash Flows Relating to Reserves (Continued)

 

The following reconciles the change in the standardized measure of discounted future net cash flows applicable to proved oil and gas reserves:

 

     2012     2013  
     (dollars in thousands)  

Beginning of Year

   $ 1,139      $ 72,268   

Sales of Oil and Gas Produced, Net of Production Cost

     (12,051     (73,949

Net Changes in Prices and Production Costs

     138        26,297   

Extensions, Discoveries, and Improved Recovery, Less Related Costs

     75,153        727,999   

Development Costs Incurred During the Year Which Were Previously Estimated

     —          31,584   

Net Change in Estimated Future Development Costs

     —          1,066   

Revisions to Previous Quantity Estimates

     2,104        86,713   

Net Change from Purchases and Sales of Minerals in Place

     —          —     

Accretion of Discount

     5,766        6,858   

Other

     19        (20,486
  

 

 

   

 

 

 

End of Year

   $ 72,268      $ 858,350   
  

 

 

   

 

 

 

 

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GLOSSARY OF SELECTED OIL AND NATURAL GAS TERMS

 

We are in the business of exploring for and producing oil and natural gas. Oil and natural gas exploration is a specialized industry. Many of the terms used to describe our business are unique to the oil and natural gas industry. The following is a description of the meanings of some of the oil and natural gas industry terms used in this document.

 

3D seismic data.    Geophysical data that depicts the subsurface strata in three dimensions.

 

Area of mutual interest or AMI.    A geographic location in which more than one oil and/or natural gas company has a stake. The area of mutual interest is defined by the contract that describes the geographic area contained in the area of mutual interest, the rights each party has (such as the percentage of interest allocated to each company), the length of time during which the contract will be in effect, and how the contract provisions are to be implemented.

 

Analogous reservoir.    Analogous reservoirs, as used in resource assessments, have similar rock and fluid properties, reservoir conditions (depth, temperature, and pressure) and drive mechanisms, but are typically at a more advanced stage of development than the reservoir of interest and thus may provide concepts to assist in the interpretation of more limited data and estimation of recovery. When used to support proved reserves, analogous reservoir refers to a reservoir that shares all of the following characteristics with the reservoir of interest: (i) the same geological formation (but not necessarily in pressure communication with the reservoir of interest; (ii) the same environment of deposition; (iii) similar geologic structure; and (iv) the same drive mechanism.

 

Basin.    A large natural depression on the earth’s surface in which sediments accumulate.

 

Bbl.    One stock tank barrel, or 42 U.S. gallons liquid volume, of oil or other liquid hydrocarbons.

 

Boe.    Barrels of oil equivalent, with 6,000 cubic feet of natural gas being equivalent to one barrel of oil.

 

Btu or British thermal unit.    The quantity of heat required to raise the temperature of one pound of water by one degree Fahrenheit.

 

Completion.    The installation of permanent equipment for the production of oil or natural gas.

 

Deterministic method.    The method of estimating reserves or resources is called deterministic when a single value for each parameter (from the geoscience, engineering or economic data) in the reserves calculation is used in the reserves estimation procedure.

 

Developed acreage.    The number of acres that are allocated or assignable to productive wells or wells capable of production.

 

Development costs.    Capital costs incurred in the acquisition, exploration, development and revisions of proved oil and natural gas reserves divided by proved reserve additions.

 

Development well.    A well drilled within the proved boundaries of an oil or natural gas reservoir with the intention of completing the stratigraphic horizon known to be productive.

 

Dry hole.    A well found to be incapable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of such production exceeds production expenses and taxes.

 

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Economically producible or viable.    The term economically producible or economically viable, as it relates to a resource, means a resource that generates revenue that exceeds, or is reasonably expected to exceed, the costs of the operation. The value of the products that generate revenue shall be determined at the terminal point of oil and natural gas producing activities.

 

Estimated ultimate recovery or EUR.    Estimated ultimate recovery is the sum of reserves remaining as of a given date and cumulative production as of that date.

 

Exploitation.    Optimizing oil and natural gas production from producing properties or establishing additional reserves in producing areas through additional drilling or the application of new technology.

 

Exploratory well.    A well drilled to find and produce oil or natural gas reserves not classified as proved, to find a new reservoir in a field previously found to be productive of oil or natural gas in another reservoir or to extend a known reservoir.

 

Field.    An area consisting of either a single reservoir or multiple reservoirs all grouped on or related to the same individual geological structural feature and/or stratigraphic condition.

 

Gross acres or gross wells.    The total acres or wells, as the case may be, in which a working interest is owned.

 

Held by production acreage.    Acreage covered by a mineral lease that perpetuates a company’s right to operate a property as long as the property produces a minimum paying quantity of oil or gas.

 

Horizontal well.    A well in which a portion of the well has been drilled horizontally within a productive or potentially productive formation. This operation usually results in the ability of the well to produce higher volumes than a vertical well drilled in the same formation.

 

Hydraulic fracturing.    The technique of improving a well’s production or injection rates by pumping a mixture of fluids into the formation and rupturing the rock, creating an artificial channel. As part of this technique, sand or other material may also be injected into the formation to keep the channel open, so that fluids or natural gases may more easily flow through the formation.

 

Injection.    A well which is used to place liquids or natural gases into the producing zone during secondary/tertiary recovery operations to assist in maintaining reservoir pressure and enhancing recoveries from the field.

 

MBoe.    Thousand barrels of oil equivalent.

 

Mcf.    Thousand cubic feet of natural gas.

 

MMBtu.    Million British Thermal Units.

 

Net acres or net wells.    The sum of the fractional working interests owned in gross acres or wells, as the case may be.

 

NYMEX.    New York Mercantile Exchange.

 

Overriding royalty interest.    A fractional, undivided interest or right of participation in the oil or natural gas, or in the proceeds from the sale of the oil or natural gas, produced from a specified tract or tracts, which is limited in duration to the terms of an existing lease and which is not subject to any portion of the expense of development, operation or maintenance.

 

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Pad.    A temporary drilling location generally consisting of 4-5 acres that is cleared, leveled and surfaced over for siting a drilling rig, trucks and various other equipment required for drilling and completion activities.

 

Probabilistic method.    The method of estimation of reserves or resources is called probabilistic when the full range of values that could reasonably occur for each unknown parameter (from the geoscience and engineering data) is used to generate a full range of possible outcomes and their associated probabilities of occurrence.

 

Productive well.    A well that is producing or is capable of production, including natural gas wells awaiting pipeline connections to commence deliveries and oil wells awaiting connection to production facilities.

 

Prospect.    A specific geographic area which, based on supporting geological, geophysical or other data and also preliminary economic analysis using reasonably anticipated prices and costs, is deemed to have potential for the discovery of commercial hydrocarbons.

 

Proved oil and natural gas reserves or Proved reserves.    Proved oil and natural gas reserves are those quantities of oil and natural gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulation prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for estimation. The project to extract the hydrocarbons must have commenced, or the operator must be reasonably certain that it will commence the project, within a reasonable time.

 

The area of the reservoir considered as proved includes all of the following: (i) the area identified by drilling and limited by fluid contacts, if any; and (ii) adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil and natural gas on the basis of available geoscience and engineering data.

 

In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons as seen in a well penetration unless geoscience, engineering or performance data and reliable technology establish a lower contact with reasonable certainty. Where direct observation from well penetrations has defined a highest known oil elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering or performance data and reliable technology establish the higher contact with reasonable certainty.

 

Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: (i) successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and (ii) the project has been approved for development by all necessary parties and entities, including governmental entities.

 

Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the twelve-month first day of the month historical average price during the twelve-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions.

 

Proved undeveloped reserves.    Proved undeveloped oil and natural gas reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. Reserves on undrilled acreage are limited to those drilling units

 

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offsetting productive units that are reasonably certain of production when drilled. Proved reserves for other undrilled units are claimed only where it can be demonstrated with certainty that there is continuity of production from the existing productive formation. Estimates for proved undeveloped reserves will not be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual tests in the area and in the same reservoir.

 

Reasonable certainty.    If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate. A high degree of confidence exists if the quantity is much more likely to be achieved than not, and, as changes due to increased availability of geoscience (geological, geophysical and geochemical), engineering and economic data are made to estimated ultimate recovery with time, reasonably certain estimated ultimate recovery is much more likely to increase or remain constant than to decrease.

 

Reliable technology.    Reliable technology is a grouping of one or more technologies (including computational methods) that has been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation.

 

Reserves.    Reserves are estimated remaining quantities of oil and natural gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and natural gas or related substances to market and all permits and financing required to implement the project.

 

Reservoir.    A porous and permeable underground formation containing a natural accumulation of producible oil and/or natural gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs.

 

Resource play.    These plays develop over long periods of time, well-by-well, in large-scale operations. They typically have lower than average long-term decline rates and lower geological and commercial development risk than conventional plays. Unlike most conventional exploration and development, resource plays are relatively predictable in timing, costs, production rates and reserve additions which can provide steady long-term reserves and production growth.

 

Resources.    Resources are quantities of oil and natural gas estimated to exist in naturally occurring accumulations. A portion of the resources may be estimated to be recoverable and another portion may be considered unrecoverable. Resources include both discovered and undiscovered accumulations.

 

Stratigraphic horizon.    A sealed geologic container capable of retaining hydrocarbons that was formed by changes in rock type or pinch-outs, unconformities, or sedimentary features such as reefs.

 

Undeveloped acreage.    Lease acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil or natural gas regardless of whether or not such acreage contains proved reserves.

 

Undeveloped oil and natural gas reserves or Undeveloped reserves.    Undeveloped oil and natural gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances. Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years,

 

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unless the specific circumstances justify a longer time. Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, or by other evidence using reliable technology establishing reasonable certainty.

 

Working interest.    The operating interest that gives the owner the right to drill, produce and conduct operating activities on the property and receive a share of production.

 

Workover.    The repair or stimulation of an existing production well for the purpose of restoring, prolonging or enhancing the production of hydrocarbons.

 

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             Shares

 

LOGO

 

Energy & Exploration Partners, Inc.

 

Common Stock

$         Per Share

 

 

 

PROSPECTUS

 

                    , 2014

 

 

 

Citigroup

 

Credit Suisse

 

RBC Capital Markets

 

 

 

 


Table of Contents

PART II

INFORMATION NOT REQUIRED IN PROSPECTUS

 

ITEM 13. Other Expenses of Issuance and Distribution

 

The following table sets forth an itemized statement of the amounts of all expenses (excluding underwriting discounts) payable by us in connection with the registration of our common stock offered hereby. With the exception of the Registration Fee, FINRA Filing Fee and New York Stock Exchange listing fee, the amounts set forth below are estimates.

 

SEC Registration Fee

   $ 51,520   

FINRA Filing Fee

     60,500   

New York Stock Exchange listing fee

         *   

Accounting fees and expenses

         *   

Auditor fees and expenses

         *   

Legal fees and expenses

         *   

Printing and engraving expenses

         *   

Transfer agent and registrar fees

         *   

Miscellaneous

         *   
  

 

 

 

Total

             *   
  

 

 

 

 

*   To be provided by amendment.

 

ITEM 14. Indemnification of Directors and Officers

 

Our amended and restated certificate of incorporation will provide that a director will not be liable to the corporation or its stockholders for monetary damages for breach of fiduciary duty as a director, except for liability (1) for any breach of the director’s duty of loyalty to the corporation or its stockholders, (2) for acts or omissions not in good faith or which involved intentional misconduct or a knowing violation of the law, (3) under section 174 of the DGCL for unlawful payment of dividends or improper redemption of stock or (4) for any transaction from which the director derived an improper personal benefit. In addition, if the DGCL is amended to authorize the further elimination or limitation of the liability of directors, then the liability of a director of the corporation, in addition to the limitation on personal liability provided for in our certificate of incorporation, will be limited to the fullest extent permitted by the amended DGCL.

 

Section 145 of the DGCL provides that a corporation may indemnify directors and officers as well as other employees and individuals against expenses, including attorneys’ fees, judgments, fines and amounts paid in settlement in connection with specified actions, suits and proceedings whether civil, criminal, administrative, or investigative, other than a derivative action by or in the right of the corporation, if they acted in good faith and in a manner they reasonably believed to be in or not opposed to the best interests of the corporation and, with respect to any criminal action or proceeding, had no reasonable cause to believe their conduct was unlawful. A similar standard is applicable in the case of derivative actions, except that indemnification extends only to expenses, including attorneys’ fees, incurred in connection with the defense or settlement of such action and the statute requires court approval before there can be any indemnification where the person seeking indemnification has been found liable to the corporation. The statute provides that it is not exclusive of other indemnification that may be granted by a corporation’s certificate of incorporation, bylaws, disinterested director vote, stockholder vote, agreement or otherwise.

 

Our amended and restated certificate of incorporation and bylaws will contain indemnification rights for our directors and our officers. Specifically, our amended and restated certificate of incorporation and amended and restated bylaws will provide that we shall indemnify, and advance expenses to, our officers and directors to the fullest extent authorized by the DGCL.

 

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We will enter into written indemnification agreements with our directors and officers. Under these proposed agreements, if an officer or director makes a claim of indemnification to us, a majority of the independent directors, independent legal counsel or stockholders, as applicable in accordance with the terms of the agreement, must review the relevant facts and make a determination whether the officer or director has met the standards of conduct under Delaware law that would permit (under Delaware law) and require (under the indemnification agreement) us to indemnify the officer or director.

 

Further, we may maintain insurance on behalf of our officers, and directors against expense, liability or loss asserted incurred by them in their capacities as officers and directors, and on behalf of some of our employees for certain liabilities.

 

ITEM 15. Recent Sales of Unregistered Securities

 

In connection with our formation on July 31, 2012, we issued 1,000 shares of our common stock, par value $0.01 per share, to Hunt Pettit in exchange for consideration of $1,000.

 

On August 22, 2012, in connection with our corporate reorganization, we issued an aggregate of 396,500 shares of our common stock to a group of accredited investors in exchange for certain interests owned by them.

 

During the period from August 22, 2012 to October 1, 2013, we issued an aggregate of 150,530 restricted shares of our common stock to certain members of our management under our 2012 Stock Incentive Plan pursuant to Restricted Stock Award Agreements. Hunt Pettit contributed 25,000 of his shares of common stock back to us for no consideration, and these shares were used by us to make some of the restricted share awards.

 

On April 8, 2013 we issued to Highbridge and Apollo notes in the principal amount of $140 million and warrants to purchase an aggregate of 269,231 shares of our Series A Mandatorily Convertible Preferred Stock and Series B Mandatorily Convertible Preferred Stock at an exercise price of $0.01 per share, which we refer to as our mandatorily convertible preferred stock. On December 12, 2013, we issued to Highbridge and Apollo notes in the principal amount of $25 million. On January 31, 2014, we issued to Highbridge and Apollo notes in the principal amount of $15 million. On March 27, 2014, we issued to Highbridge and Apollo notes in the principal amount of $45 million and warrants to purchase an aggregate of 71,122 shares of our mandatorily convertible preferred stock at an exercise price of $0.01 per share.

 

On July 22, 2014, we issued $375,000,000 in aggregate principal amount of our 8.0% convertible subordinated notes due 2019, which we refer to as convertible notes, in a private placement transaction to qualified institutional buyers in reliance on Rule 144A under the Securities Act of 1933, as amended, which we refer to as the Securities Act. The convertible notes are convertible into shares of our common stock in connection with a qualified, registered public offering of our common stock.

 

The foregoing issuances of securities did not involve any underwriters, underwriting discounts or commissions, or any public offering, and we believe the issuances were exempt from the registration requirements of the Securities Act pursuant to Section 4(a)(2) thereunder, and in the case of the restricted shares awarded to certain members of management, pursuant to Rule 701 under the Securities Act, and in the case of the convertible notes, pursuant to Rule 144A under the Securities Act.

 

ITEM 16. Exhibits and Financial Statement Schedules

 

(a) Exhibits

 

A list of exhibits filed as part of this registration statement is set forth in the Index to Exhibits, which is incorporated herein by reference.

 

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ITEM 17. Undertakings

 

The undersigned registrant hereby undertakes to provide to the underwriters at the closing specified in the underwriting agreement certificates in such denominations and registered in such names as required by the underwriters to permit prompt delivery to each purchaser.

 

Insofar as indemnification for liabilities arising under the Securities Act may be permitted to directors, officers and controlling persons of the registrant pursuant to the foregoing provisions, or otherwise, the registrant has been advised that in the opinion of the Securities and Exchange Commission such indemnification is against public policy as expressed in the Securities Act and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the registrant of expenses incurred or paid by a director, officer or controlling person of the registrant in the successful defense of any action, suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered, the registrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Securities Act and will be governed by the final adjudication of such issue.

 

The undersigned registrant hereby undertakes that:

 

(1) For purposes of determining any liability under the Securities Act, the information omitted from the form of prospectus filed as part of this registration statement in reliance upon Rule 430A and contained in a form of prospectus filed by the registrant pursuant to Rule 424(b)(1) or (4) or 497(h) under the Securities Act shall be deemed to be part of this registration statement as of the time it was declared effective.

 

(2) For the purpose of determining any liability under the Securities Act, each post-effective amendment that contains a form of prospectus shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.

 

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SIGNATURES

 

Pursuant to the requirements of the Securities Act of 1933, the registrant has duly caused registration statement on Form S-1 to be signed on its behalf by the undersigned, thereunto duly authorized in the City of Fort Worth, State of Texas, on September 12, 2014.

 

ENERGY & EXPLORATION PARTNERS, INC.

By:

 

/s/ B. Hunt Pettit

Name:   B. Hunt Pettit
Title:   President and Chief Executive Officer

 

POWER OF ATTORNEY

 

Each person whose signature appears below appoints B. Hunt Pettit and Tom D. McNutt, and each of them, any of whom may act without the joinder of the other, as his true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to sign any and all amendments (including post-effective amendments) to this Registration Statement and any Registration Statement (including any amendment thereto) for this offering that is to be effective upon filing pursuant to Rule 462(b) under the Securities Act of 1933, as amended, and to file the same, with all exhibits thereto, and all other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he might or would do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them or their or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

 

Pursuant to the requirements of the Securities Act of 1933, this registration statement on Form S-1 has been signed by the following persons in the capacities and on the date indicated.

 

Signature

  

Title

 

Date

/s/ B. Hunt Pettit

B. Hunt Pettit

  

President, Chief Executive Officer

and Director (principal executive officer)

  September 12, 2014

/s/ Brian C. Nelson

Brian C. Nelson

   Executive Vice President, Chief Financial Officer and Director (principal financial officer)   September 12, 2014

/s/ Jamie M. Howe

Jamie M. Howe

   Executive Vice President and Chief Accounting Officer (principal accounting officer)   September 12, 2014

/s/ David L. Patty, Jr.

David L. Patty, Jr.

   Director   September 12, 2014

/s/ Lawrence B. Van Ingen

Lawrence B. Van Ingen

   Director   September 12, 2014

 

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Signature

  

Title

 

Date

/s/ Tom D. McNutt

Tom D. McNutt

   Director   September 12, 2014

/s/ John T. Richards

John T. Richards

   Director   September 12, 2014

/s/ Don Dimitrievich

Don Dimitrievich

   Director   September 12, 2014

 

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INDEX TO EXHIBITS

 

Exhibit
Number

    

Description

  1.1*       Form of Underwriting Agreement
  2.1†       Purchase and Sale Agreement dated as of June 13, 2014 between Energy & Exploration Partners, LLC and TreadStone Energy Partners, LLC
  2.2†       Amended and Restated Purchase and Sale Agreement dated as of October 8, 2012 among Energy & Exploration Partners, LLC, Chesapeake Exploration, L.L.C., Arcadia Resources, L.P. and Jamestown Resources L.L.C. (incorporated herein by reference to Exhibit 2.12 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  2.3†       First Amendment to Amended and Restated Purchase and Sale Agreement dated as of December 28, 2012 among Energy & Exploration Partners, LLC, Chesapeake Exploration, L.L.C., Arcadia Resources, L.P. and Jamestown Resources L.L.C. (incorporated herein by reference to Exhibit 2.17 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  2.4†       Second Amendment to Amended and Restated Purchase and Sale Agreement dated as of April 8, 2013 among Energy & Exploration Partners, LLC, Chesapeake Exploration, L.L.C., Arcadia Resources, L.P. and Jamestown Resources L.L.C. (incorporated herein by reference to Exhibit 2.18 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  2.5†       Purchase and Sale Agreement dated as of March 5, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (formerly RWG Energy, Inc.) (incorporated herein by reference to Exhibit 2.2 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.6†       First Amendment to Purchase and Sale Agreement dated as of April 19, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.7       Second Amendment to Purchase and Sale Agreement dated as of May 10, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.4 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.8†       Third Amendment to Purchase and Sale Agreement dated as of May 24, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.5 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.9†       Fourth Amendment to Purchase and Sale Agreement dated as of June 21, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.6 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.10       Fifth Amendment to Purchase and Sale Agreement dated as of July 16, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.7 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)

 

II-6


Table of Contents

Exhibit
Number

    

Description

  2.11†       Sixth Amendment to Purchase and Sale Agreement dated as of July 31, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.8 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.12       Seventh Amendment to Purchase and Sale Agreement dated as of August 29, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.9 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.13       Eighth Amendment to Purchase and Sale Agreement dated as of September 13, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.13 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  2.14†       Ninth Amendment to Purchase and Sale Agreement dated as of September 17, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.14 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  2.15†       Letter Agreement dated as of October 10, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. re Notice of Acquisition of Mineral Interest in AMI 1 (incorporated herein by reference to Exhibit 2.15 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  2.16†       Letter Agreement dated as of October 12, 2012 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. re Notice of Acquisition of Mineral Interest in AMI 2 (incorporated herein by reference to Exhibit 2.16 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  2.17       Letter Agreement dated as of March 4, 2013 between Energy & Exploration Partners, LLC and Halcón Energy Properties, Inc. (incorporated herein by reference to Exhibit 2.19 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  2.18†       Purchase and Sale Agreement dated as of August 23, 2012 between Energy & Exploration Partners, LLC and CEU Huntsville, LLC (incorporated herein by reference to Exhibit 2.11 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  2.19       Contribution Agreement dated as of August 22, 2012 among Energy & Exploration Partners, Inc., Hunt Pettit, H Pettit HC, Inc., the Fund Limited Partners identified therein, the Niobrara Investors identified therein and Energy & Exploration Partners, LLC (incorporated herein by reference to Exhibit 2.1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  3.1*       Form of Amended and Restated Certificate of Incorporation of Energy & Exploration Partners, Inc.
  3.2*       Form of Amended and Restated Bylaws of Energy & Exploration Partners, Inc.
  3.3       Certificate of Designations of Series A Mandatorily Convertible Preferred Stock of Energy & Exploration Partners, Inc. (incorporated herein by reference to Exhibit 3.3 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)

 

II-7


Table of Contents

Exhibit
Number

    

Description

  3.4       Certificate of Designations of Series B Mandatorily Convertible Preferred Stock of Energy & Exploration Partners, Inc. (incorporated herein by reference to Exhibit 3.4 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  3.5       Certificate of Amendment to Certificate of Designations of Series A Mandatorily Converted Preferred Stock of Energy & Exploration Partners, Inc. dated March 26, 2014 (incorporated herein by reference to Exhibit 3.5 to Amendment No. 5 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed April 4, 2014)
  3.6       Certificate of Amendment to Certificate of Designations of Series B Mandatorily Converted Preferred Stock of Energy & Exploration Partners, Inc. dated March 26, 2014 (incorporated herein by reference to Exhibit 3.6 to Amendment No. 5 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed April 4, 2014)
  3.7       Certificate of Amendment to Certificate of Designations of Series A Mandatorily Converted Preferred Stock of Energy & Exploration Partners, Inc. dated July 22, 2014
  3.8       Certificate of Amendment to Certificate of Designations of Series B Mandatorily Converted Preferred Stock of Energy & Exploration Partners, Inc. dated July 22, 2014
  4.1       Indenture dated as of July 22, 2014 among Energy & Exploration Partners, Inc. and U.S. Bank National Association, as trustee, relating to the 8.0% Convertible Subordinated Notes due 2019 (including form of Note)
  4.2       Registration Rights Agreement dated as of July 22, 2014 among Energy & Exploration Partners, Inc. and Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC/Sea Port Group Securities, LLC
  4.3       Second Amended and Restated Registration Rights Agreement dated as of July 10, 2014 among Energy & Exploration Partners, Inc. and its stockholders and warrantholders named therein
  4.4       Second Amended and Restated Stockholders Agreement dated as of July 10, 2014 among Energy & Exploration Partners, Inc. and its stockholders and warrantholders named therein
  4.5       Form of Warrant to Purchase Series A Preferred Stock (incorporated herein by reference to Exhibit 4.1 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  4.6       Form of Warrant to Purchase Series B Preferred Stock (incorporated herein by reference to Exhibit 4.2 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  4.7       Form of Amendment to Warrant to Purchase Series A Preferred Stock
  4.8       Form of Amendment to Warrant to Purchase Series B Preferred Stock
  4.9       Form of Second Amendment to Warrant to Purchase Series B Preferred Stock
  5.1*       Opinion of Bracewell & Giuliani LLP as to the legality of the securities being registered
  10.1       Credit Agreement dated as of July 22, 2014 among the Company, as Holdings, Energy & Exploration Partners, LLC, as Borrower, the Lenders party thereto and Credit Suisse AG, Cayman Islands Branch, as Administrative Agent and Collateral Agent
  10.2       Energy & Exploration Partners, Inc. 2012 Stock Incentive Plan (incorporated herein by reference to Exhibit 10.9 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)

 

II-8


Table of Contents

Exhibit
Number

    

Description

  10.3*       Form of Employment Agreement for executive officers
  10.4       Form of Indemnification Agreement between Energy & Exploration Partners, Inc. and each of its executive officers and directors (incorporated herein by reference to Exhibit 10.13 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.5       Form of Restricted Stock Award Agreement (incorporated herein by reference to Exhibit 10.10 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  10.6       Restricted Stock Award Agreement dated as of August 22, 2012 between Energy & Exploration Partners, Inc. and Brian C. Nelson (incorporated herein by reference to Exhibit 10.11 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed September 10, 2012)
  10.7       First Amendment to Restricted Stock Award Agreement dated as of November 16, 2012 between Energy & Exploration Partners, Inc. and Brian C. Nelson (incorporated herein by reference to Exhibit 10.33 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  10.8       Second Amendment to Restricted Stock Award Agreement dated as of December 1, 2013 between Energy & Exploration Partners, Inc. and Brian C. Nelson (incorporated herein by reference to Exhibit 10.42 to Amendment No. 5 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed April 4, 2014)
  10.9       Third Amendment to Restricted Stock Award Agreement dated as of March 31, 2014 between Energy & Exploration Partners, Inc. and Brian C. Nelson
  10.10       Restricted Stock Award Agreement dated as of August 22, 2012 between Energy & Exploration Partners, Inc. and Tom D. McNutt (incorporated herein by reference to Exhibit 10.34 to Amendment No. 5 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed April 4, 2014)
  10.11       First Amendment to Restricted Stock Award Agreement dated as of November 16, 2012 between Energy & Exploration Partners, Inc. and Tom D. McNutt (incorporated herein by reference to Exhibit 10.35 to Amendment No. 5 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed April 4, 2014)
  10.12       Second Amendment to Restricted Stock Award Agreement dated as of December 1, 2013 between Energy & Exploration Partners, Inc. and Tom D. McNutt (incorporated herein by reference to Exhibit 10.43 to Amendment No. 5 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed April 4, 2014)
  10.13       Subordinated Unsecured Note dated as of April 8, 2013 from Energy & Exploration Partners, Inc. to Chesapeake Exploration, L.L.C. (incorporated herein by reference to Exhibit 10.38 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed March 13, 2013)
  10.14       Assignment of Overriding Royalty dated as of August 20, 2012 among BHP Consulting LP and the assignees party thereto (incorporated herein by reference to Exhibit 10.14 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)

 

II-9


Table of Contents

Exhibit
Number

    

Description

  10.15       Assignment of Overriding Royalty dated as of August 20, 2012 among TDM Holding, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.15 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.16       Assignment of Overriding Royalty dated as of August 29, 2012 among TDM Holding, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.16 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.17       Assignment of Overriding Royalty dated as of August 20, 2012 among INDY Exploration II, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.17 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.18       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.18 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.19       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.19 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.20       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.20 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.21       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.21 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.22       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.22 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.23       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.23 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.24       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.24 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.25       Assignment of Overriding Royalty dated as of August 20, 2012 among Energy & Exploration Partners, LLC and the assignees party thereto (incorporated herein by reference to Exhibit 10.25 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)

 

II-10


Table of Contents

Exhibit
Number

    

Description

  10.26       Stipulation of Interest dated as of August 20, 2012 among Energy & Exploration Partners, LLC, Halcón Energy Properties, Inc., and the assignees party thereto (incorporated herein by reference to Exhibit 10.26 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.27       Stipulation of Interest dated as of August 20, 2012 among Energy & Exploration Partners, LLC, Halcón Energy Properties, Inc., and TDM Holding, LLC (incorporated herein by reference to Exhibit 10.27 to Amendment No. 1 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed October 17, 2012)
  10.28    Form of Amended and Restated Energy & Exploration Partners, Inc. 2012 Stock Incentive Plan
  21.1       Subsidiaries of Energy & Exploration Partners, Inc.
  23.1       Consent of Hein & Associates LLP
  23.2*       Consent of Bracewell & Giuliani LLP (included as part of Exhibit 5.1 hereto)
  23.3       Consent of Cawley, Gillespie & Associates, Inc. with respect to Energy & Exploration Partners, LLC Interests
  23.4       Consent of LaPorte, A Professional Accounting Corporation
  23.5       Consent of Cawley, Gillespie & Associates, Inc. with respect to Treadstone Energy Partners Acquisition Interests
  24.1       Power of Attorney (included on the signature page of this Registration Statement)
  99.1       Consent of Drilling Info, Inc.
  99.2       Reserve Report of Cawley, Gillespie & Associates, Inc. as of December 31, 2012 (incorporated herein by reference to Exhibit 99.3 to Amendment No. 3 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed May 13, 2013)
  99.3       Reserve Report of Cawley, Gillespie & Associates, Inc. as of December 31, 2013 (incorporated herein by reference to Exhibit 99.4 to Amendment No. 6 to the Company’s Registration Statement on Form S-1 (Registration No. 333-183808) filed April 4, 2014)
  99.4       Reserve Report of Cawley, Gillespie & Associates, Inc. as of June 1, 2014 for Energy & Exploration Partners, LLC Interests
  99.5       Reserve Report of Cawley, Gillespie & Associates, Inc. as of June 1, 2014 for Treadstone Energy Partners Acquisition Interests

 

*   To be filed by amendment.
  The schedules and exhibits to this agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The registrant will furnish supplementally a copy of each such schedule and exhibit to the Securities and Exchange Commission upon request.

 

II-11



Exhibit 2.1

Execution Version

Purchase and Sale Agreement

TreadStone Energy Partners, LLC,

as Seller

and

Energy & Exploration Partners, LLC,

as Buyer

Dated June 13, 2014


TABLE OF CONTENTS

 

         Page  

Article I.

 

Definitions and References

     1   

Section 1.1

 

Defined Terms

     1   

Article II.

 

Properties to be Sold and Purchased

     9   

Section 2.1

 

Properties

     9   

Section 2.2

 

Excluded Properties

     11   

Article III.

 

Purchase Price

     12   

Section 3.1

 

Purchase Price

     12   

Section 3.2

 

Allocated Values

     13   

Article IV.

 

Representations of Seller

     13   

Section 4.1

 

Formation and Qualification

     13   

Section 4.2

 

Power and Authority

     13   

Section 4.3

 

Valid, Binding, and Enforceable

     14   

Section 4.4

 

Approvals; Non-Contravention

     14   

Section 4.5

 

Royalties

     14   

Section 4.6

 

Litigation

     14   

Section 4.7

 

Leases

     14   

Section 4.8

 

Commitments, Abandonments, or Proposals

     15   

Section 4.9

 

Preferential Rights; Consents

     15   

Section 4.10

 

Payments for Production

     15   

Section 4.11

 

Contracts

     16   

Section 4.12

 

Affiliate Transactions

     17   

Section 4.13

 

Imbalances

     17   

Section 4.14

 

Compliance with Laws

     17   

Section 4.15

 

Environmental Matters

     17   

Section 4.16

 

Tax Matters

     18   

Section 4.17

 

Suspense Accounts

     18   

Section 4.18

 

No Brokers

     18   

Section 4.19

 

No Bankruptcy

     19   

Article V.

 

Disclaimer

     19   

Section 5.1

 

Disclaimer

     19   

Article VI.

 

Representations of Buyer

     20   

Section 6.1

 

Formation and Qualification

     20   

Section 6.2

 

Power and Authority

     20   

Section 6.3

 

Approvals; Non-Contravention

     20   

Section 6.4

 

Valid, Binding, and Enforceable

     20   

Section 6.5

 

No Litigation

     21   

Section 6.6

 

Governmental and Third Person Consents

     21   

Section 6.7

 

No Brokers

     21   

Section 6.8

 

No Bankruptcy

     21   

 

- i -


Section 6.9

 

No Distribution

     21   

Section 6.10

 

Knowledge and Experience

     21   

Section 6.11

 

Opportunity to Verify Information

     21   

Section 6.12

 

Merits and Risks of an Investment in the Properties

     22   

Article VII.

 

Certain Covenants

     22   

Section 7.1

 

Access to Records

     22   

Section 7.2

 

Physical Inspection

     22   

Section 7.3

 

Exculpation and Indemnification

     23   

Section 7.4

 

Interim Operation

     23   

Section 7.5

 

Consents

     24   

Section 7.6

 

Operatorship

     25   

Section 7.7

 

HSR Act

     26   

Section 7.8

 

Exclusivity

     26   

Article VIII.

 

Due Diligence Review

     26   

Section 8.1

 

Review By Buyer

     26   

Section 8.2

 

Nature of Defects

     27   

Section 8.3

 

Permitted Matters and Encumbrances

     28   

Section 8.4

 

Seller’s Response to Asserted Defects

     30   

Section 8.5

 

Resolution of Uncured Defects

     30   

Section 8.6

 

Adjustment for Certain Uncured Defects

     31   

Section 8.7

 

Possible Upward Adjustments

     33   

Section 8.8

 

Limitations on Adjustments

     33   

Section 8.9

 

EXCLUSIVE REMEDY

     34   

Article IX.

 

Conditions Precedent to Closing Obligations

     34   

Section 9.1

 

Conditions Precedent to the Obligations of Buyer

     34   

Section 9.2

 

Conditions Precedent to the Obligations of Seller

     35   

Article X.

 

Closing

     36   

Section 10.1

 

Closing

     36   

Section 10.2

 

Seller’s Closing Obligations

     36   

Section 10.3

 

Buyer’s Closing Obligations

     37   

Article XI.

 

Termination

     38   

Section 11.1

 

Termination

     38   

Section 11.2

 

Effect of Termination

     39   

Article XII.

 

Post-Closing Actions

     40   

Section 12.1

 

Transfer of Files

     40   

Section 12.2

 

Notifications by Buyer

     40   

Section 12.3

 

Undisbursed Revenues

     40   

Section 12.4

 

Confidentiality

     40   

Section 12.5

 

Financial Matters

     42   

Section 12.6

 

Transition Services

     43   

Section 12.7

 

Tax Matters

     43   

 

- ii -


Article XIII.

 

Accounting Adjustments

     44   

Section 13.1

 

Adjustments for Revenues and Expenses

     44   

Section 13.2

 

Initial Adjustment at Closing

     45   

Section 13.3

 

Adjustment Post Closing

     46   

Section 13.4

 

No Further Adjustments

     46   

Section 13.5

 

Imbalance Adjustments

     47   

Section 13.6

 

Gas Imbalances, Makeup Obligations

     47   

Article XIV.

 

Assumption and Indemnification

     47   

Section 14.1

 

Assumption and Indemnification By Buyer

     47   

Section 14.2

 

Indemnification By Seller

     48   

Section 14.3

 

Survival of Provisions/Limitations

     49   

Section 14.4

 

Notice of Claim

     51   

Article XV.

 

Casualty Losses

     52   

Section 15.1

 

Casualty Loss

     52   

Article XVI.

 

Notices

     52   

Section 16.1

 

Notices

     52   

Article XVII.

 

Miscellaneous Matters

     53   

Section 17.1

 

Change of Name

     53   

Section 17.2

 

Further Assurances

     53   

Section 17.3

 

Waiver of Consumer Rights

     53   

Section 17.4

 

Expenses; No Special Damages

     54   

Section 17.5

 

No Transfer Taxes

     54   

Section 17.6

 

Entire Agreement

     54   

Section 17.7

 

Amendments, Waivers

     54   

Section 17.8

 

Choice of Law, etc.

     54   

Section 17.9

 

Time of Essence

     55   

Section 17.10

 

No Assignment

     55   

Section 17.11

 

Successors and Assigns

     55   

Section 17.12

 

No Press Releases

     55   

Section 17.13

 

Counterpart Execution

     55   

Section 17.14

 

Replacement Bonds, Letters of Credit, and Guaranties

     55   

Section 17.15

 

No Third Party Beneficiaries

     56   

Section 17.16

 

Arbitration

     56   

Section 17.17

 

References, Titles, and Construction

     57   

Section 17.18

 

Severability

     57   

 

- iii -


LIST OF EXHIBITS AND SCHEDULES

 

Exhibits
A    Leases
B    Wells
C    Contracts
D    Surface Rights
E    Form of Conveyance
F    Form of Transition Services Agreement
Schedules
1.1    Persons with Knowledge
3.2    Allocated Values
4.4    Required Consents
4.6    Litigation
4.7    Leases
4.8    Commitments, Abandonments, or Proposals
4.10(a)    Marketing Agreements
4.10(b)    Payments for Production
4.11    Contracts
4.13    Imbalances
4.14    Compliance with Laws
4.15    Environmental Matters
4.17    Suspended Funds
7.4    Interim Operations
12.7    Tax Matters

 

- iv -


PURCHASE AND SALE AGREEMENT

This Purchase and Sale Agreement, dated June 13, 2014, is by and between TreadStone Energy Partners, LLC, a Delaware limited liability company (“Seller”), and Energy & Exploration Partners, LLC, a Delaware limited liability company (“Buyer”).

W I T N E S S E T H:

WHEREAS, Seller desires to sell, assign, and convey to Buyer, and Buyer desires to purchase and accept, the Properties (as defined herein) located in Houston and Madison Counties, Texas, in the manner and upon the terms and conditions hereafter set forth.

NOW, THEREFORE, in consideration of the mutual covenants and agreements contained herein, and other valuable consideration, the receipt and sufficiency of which are hereby acknowledged, Seller and Buyer do hereby agree as follows:

Article I.

Definitions and References

Section 1.1 Defined Terms. When used in this Agreement, the following terms shall have the respective meanings assigned to them in this Section 1.1 or in the section, subsections, or other subdivisions referred to below:

Additional Testing” shall have the meaning assigned to such term in Section 7.2.

Additional Testing Notice” shall have the meaning assigned to such term in Section 7.2.

Affiliate” means, with respect to any Person, a Person that directly or indirectly controls, is controlled by, or is under common control with, such Person, with control in such context meaning the ability to direct the management or policies of a Person through ownership of voting shares or other securities, pursuant to a written agreement, or otherwise.

Aggregate Deductible” shall have the meaning assigned to such term in Section 8.8.

Agreement” means this Purchase and Sale Agreement, including all schedules and exhibits hereto, as hereafter changed, amended, modified, or restated in accordance with the terms hereof.

Allocated Value” shall have the meaning assigned to such term in Section 3.2.

Applicable Environmental Laws” mean, as the same may have been amended as of the Effective Time, all federal, state or local laws, rules, orders or regulations addressing or governing protection of the environment, pollution, or Hazardous Substances, including the Clean Air Act, 42 U.S.C. § 7401 et seq.; the Federal Water Pollution Control Act, 33 U.S.C. § 1251 et seq., the Oil Pollution Act of 1990, 33 U.S.C. § 2701 et seq.; the National Environmental Policy Act, 42 U.S.C. § 4321 et seq.; the Resource Conservation and Recovery Act, 42 U.S.C. § 6901 et seq., as amended by the Hazardous and Solid Waste Amendments of 1984 (“RCRA”); the Hazardous Materials Transportation Act, 49 U.S.C. § 1471 et seq.; the


Toxic Substances Control Act, 15 U.S.C. §§ 2601 through 2629; the Oil Pollution Act, 33 U.S.C. § 2701 et seq.; the Safe Drinking Water Act, 42 U.S.C. § 300f et seq.; the Comprehensive Environmental Response, Compensation and Liability Act, 42 U.S.C. § 9601 et seq., as amended by the Superfund Amendments and Reauthorization Act, and the Emergency Planning and Community Right-to-Know Act, 42 U.S.C. § 11001 et seq. Notwithstanding the foregoing, the phrase “violation of Environmental Laws” and words of similar import used herein shall mean, as to any given Oil and Gas Property, the violation of or failure to meet specific objective requirements or standards that are clearly applicable to such Oil and Gas Property under Applicable Environmental Laws where such requirements or standards are in effect as of the Effective Time.

Asserted Defects” shall have the meaning assigned to such term in Section 8.1.

Base Purchase Price” shall have the meaning assigned to such term in Section 3.1.

Business Day” means any day other than a Saturday, Sunday, or other day on which commercial banks in Houston, Texas, are required or authorized by Law to be closed.

Buyer’s Indemnified Claim” and “Buyer’s Indemnified Claims” shall have the meanings assigned to such terms in Section 14.2.

Buyer Indemnified Parties” shall have the meaning assigned to such term in Section 14.2.

Casualty Loss” shall have the meaning assigned to such term in Section 15.1.

Claim Notice” shall have the meaning assigned to such term in Section 14.4.

Closing” and “Closing Date” shall have the meanings assigned to such terms in Section 10.1.

Code” shall have the meaning assigned to such term in Section 3.2.

Confidentiality Agreement” means the Confidentiality Agreement between Buyer and Seller dated April 1, 2014.

Confidential Information” shall have the meaning assigned to such term in Section 12.4(b).

Consent” shall have the meaning assigned to such term in Section 7.5(a).

Contracts” shall have the meaning assigned to such term in Section 2.1(d).

Conveyance” shall have the meaning assigned to such term in Section 10.2(a).

Credit Agreement” shall mean (x) that certain Loan Agreement dated February 5, 2013, by and between Bank of Texas and Seller, (y) that certain Deed of Trust & Security Agreement dated February 5, 2013, by and between Bank of Texas and Seller, as recorded at

 

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Volume 1236, Page 255 of the Official Records of Madison County, Texas, and Instrument Number 1301088 of the Official Records of Houston County, Texas and (z) that certain Revolving Promissory Note dated February 5, 2013, by and between Bank of Texas and Seller.

Defect” shall have the meaning assigned to such term in Section 8.2.

Defect Deadline” shall have the meaning assigned to such term in Section 8.1.

Defensible Title” means that title of Seller to an Oil and Gas Property that:

(a) as to the UGR Unit or any of the Wells (including Uncompleted Wells), entitles Seller to receive, throughout the duration of the productive life of each Unit, Well, or the Leases included in such Unit or on which such Well is located (after satisfaction of all royalties, overriding royalties, nonparticipating royalties, production payments, net profits interests, and other similar burdens on or measured by production of Hydrocarbons) not less than the Net Revenue Interest shown in Exhibit B of all Hydrocarbons produced, saved, and marketed from the currently producing intervals in such Unit or Well, except for decreases (i) in connection with those operations in which Seller may be a nonconsenting co-owner, (ii) resulting from the reversion of interests to co-owners with respect to operations in which such co-owners elected not to consent, (iii) resulting from the establishment, or amendment, of pools or units, and (iv) required to allow co-owners to make up past underproduction, or pipelines to make up past under-deliveries, insofar as, in each case, such decreases and reductions are expressly reflected in and taken into account in Exhibit B;

(b) as to the UGR Unit or any of the Wells (including Uncompleted Wells), obligates Seller to bear a percentage of the costs and expenses for the maintenance and development of, and operations relating to, each Unit or Well, or the Leases included in such Unit or on which such Well is located, that is not greater than the Working Interest shown for such Unit or Well in Exhibit B, without increase throughout the productive life of such Well or Unit, or the Leases included in such Unit or on which such Well is located, except increases (i) resulting from contribution requirements with respect to defaulting co-owners under applicable operating agreements or applicable Law and (ii) that are accompanied by at least a proportionate increase in Seller’s Net Revenue Interest, with specificity as to any reversionary, back-in, or carried interests, and any before and after payout interests, to which any such Well or Unit may be subject, insofar only as, in each case, such increases are expressly reflected, and taken into account, in Exhibit B;

(c) as to (i) Leases not within the geographic boundaries of the UGR Unit and (ii) Leases within the geographic boundaries of the UGR Unit, as to the subsurface intervals underlying such Leases located above the top, or below the base, of the Unitized Interval, (x) includes not less than the number of Net Leasehold Acres described for such Lease on Schedule 3.2, subject to such depth limitations and other restrictions as may be set forth on Schedule 3.2 or in the instruments that constitute (or are assignments or conveyances in the chain of title to) such Lease, and (y) entitles Seller to receive, throughout the productive life of such Lease (after the satisfaction of all royalties, overriding royalties, nonparticipating royalties, production payments, net profits interests, and other similar burdens on or measured by production of Hydrocarbons) not less than the Net Revenue Interest shown for such Lease on Schedule 3.2; and

 

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(d) is free and clear of all liens and encumbrances on title, except Permitted Encumbrances.

Designated Accountants” means BDO USA, LLP or any other accounting firm mutually acceptable to the Parties.

Disclosing Party” means the Party who discloses Confidential Information pursuant to this Agreement.

Effective Time” shall have the meaning assigned to such term in Section 10.2(a).

Exclusive Period” shall have the meaning assigned to such term in Section 7.8.

Excluded Properties” shall have the meaning assigned to such term in Section 2.2.

Exclusion Election” shall have the meaning assigned to such term in Section 8.4(a).

Final Settlement Date” shall have the meaning assigned to such term in Section 13.3.

Final Settlement Statement” shall have the meaning assigned to such term in Section 13.3.

Governmental Authority” means any governmental or quasi-governmental federal, state, provincial, county, city, or other political subdivision of the United States, any foreign country, or any department, bureau, agency, commission, court, or other statutory or regulatory body or instrumentality thereof.

Hazardous Substance” means any substance defined as a “hazardous substance” or as a pollutant, contaminant, or as otherwise toxic to health or the environment under Applicable Environmental Law.

HSR Act” means the Hart-Scott-Rodino Antitrust Improvement Act of 1976, as amended, and the rules and regulations promulgated thereunder.

Hydrocarbons” means crude oil, natural gas, casinghead gas, condensate, sulfur, natural gas liquids, and/or other liquid or gaseous hydrocarbons or any combination thereof or products therefrom.

Indemnitee” shall have the meaning assigned to such term in Section 14.4.

Initial Settlement Statement” shall have the meaning assigned to such term in Section 13.2.

Interest Addition” shall have the meaning assigned to such term in Section 8.7.

 

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Interest Addition Value” means, with respect to each Interest Addition asserted by Seller in a timely and proper manner under Section 8.7, the increase in value of the affected Lease, Unit, or Well as determined by Seller and Buyer as the result of the existence of the relevant Interest Addition, after taking into account the size, legal characteristics, and potential economic effect of such Interest Addition over the life of the affected Lease, Unit, or Well.

Laws” means all constitutions, treaties, laws, statutes, ordinances, rules, regulations, orders, and decrees of the United States, any foreign country, and any local, state, provincial, or federal political subdivision or agency thereof, as well as all judgments, decrees, orders, and decisions of courts having the effect of law in each such jurisdiction, including all Applicable Environmental Laws.

Leases” shall have the meaning assigned to such term in Section 2.1(a).

Losses” shall have the meaning assigned to such term in Section 14.1.

Lowest Cost Response” shall have the meaning assigned to such term in Section 8.6(d).

Material Adverse Effect” means an event, violation, inaccuracy, circumstance or other matter that, individually or in the aggregate, would materially and adversely affect the business, condition (financial or otherwise), capitalization, assets, liabilities, operations, or financial performance of the Properties, taken as a whole; provided, however, that the following shall not be deemed to constitute, create, or cause a Material Adverse Effect: any changes, circumstances, or effects that (a) affect generally the oil and gas industry, such as fluctuations in the price of Hydrocarbons, (b) result from international, national, regional, state, or local economic conditions, (c) result from general developments or conditions in the oil and gas industry, (d) result from changes in Laws (including regulatory or enforcement policy) applicable to Seller or its Affiliates, (e) result from any of the transactions contemplated by this Agreement and any public announcement thereof, (f) result from the effects of conditions or events resulting from an outbreak or escalation of hostilities (whether nationally or internationally), or the occurrence of any other calamity or crisis (whether nationally or internationally), including terrorist attacks, or (g) result from a condition that is cured or eliminated on or before Closing.

Net Leasehold Acres” means, as to each parcel or tract of Land covered by a Lease in which Seller owns an interest, the product of (a) the number of acres of Land that are included in such parcel or tract (i.e., gross acres) covered by such Lease, multiplied by (b) the lessor’s undivided mineral fee interests in the Lands included in such parcel or tract, multiplied by (c) the Seller’s Working Interest in such Lease (provided, however, that if items (b) and (c) of this definition vary as to different depths or geographic areas within any tracts or parcels burdened by such Lease, a separate calculation shall be performed with respect to each such depth or geographic area).

Net Revenue Interest” or “NRI” means the decimal interest in and to all production of the Hydrocarbons produced and saved or sold from an Oil and Gas Property, after giving effect to Seller’s contracts and all valid lessors’ royalties, overriding royalties, production payments, and/or other non-expense bearing burdens against production.

 

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NYMEX” means the New York Mercantile Exchange.

Oil and Gas Property” and “Oil and Gas Properties” shall have the meanings assigned to such terms in Section 2.1.

Outside Date” shall have the meaning assigned to such term in Section 12.5.

Parties” shall mean Buyer and Seller, including their respective successors and assigns.

Permit” shall mean the permits, licenses, authorizations, certificates, registrations, and other approvals granted by any Governmental Authority that pertain or relate in any way to the Leases, Units, and Wells.

Permitted Encumbrances” shall have the meaning assigned to such term in Section 8.3.

Person” means an individual, an estate, a corporation, a partnership, an association, a joint stock company, a limited liability company, a joint venture, a trust, an unincorporated organization and any other legally recognized entity.

Production Taxes” means any and all severance, production, gathering, Btu or gas, transportation, gross receipts, utility, excise, and other similar Taxes (other than Property-Related Taxes, Transfer Taxes, and Taxes based on or measured by net income or net worth) relating to the production, gathering, or transportation of Hydrocarbons, or increases therein, and any interest or penalties thereon.

Properties” shall have the meaning assigned to such term in Section 2.1.

Property Contracts” shall have the meaning assigned to such term in Section 4.11.

Property Costs” means all costs attributable to the ownership and operation of the Properties (including without limitation costs of insurance but excluding all Taxes) and, capital expenditures incurred in the ownership and operation of the Properties in the ordinary course of business and, where applicable, in accordance with the relevant operating agreement or unit agreement, if any, but excluding, without limitation, liabilities, losses, costs, and expenses attributable to: (a) claims, investigations, administrative proceedings, or litigation directly or indirectly arising out of or resulting from actual or claimed personal injury or death, property damage, or violation of any Law; (b) obligations to plug wells, dismantle facilities, close pits, and restore the surface around such wells, facilities, and pits; (c) obligations to remediate any contamination of groundwater, surface water, soil, or equipment under Applicable Environmental Laws; (d) obligations to furnish make-up gas according to the terms of applicable gas sales, gathering or transportation contracts; (e) gas balancing obligations; and (f) obligations to pay Working Interests, royalties, overriding royalties, or other interests held in suspense, all of which are addressed in Article XIII.

Property-Related Taxes” means any and all ad valorem, property, generation, conversion, privilege, consumption, lease, transaction, and other Taxes, franchise fees,

 

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governmental charges or fees, licenses, fees, permits, and assessments, or increases therein, and any interest or penalties thereon, other than Production Taxes, Transfer Taxes, and Taxes based on or measured by net income or net worth.

Purchase Price” shall have the meaning assigned to such term in Section 3.1.

Recipient” means the Party who receives Confidential Information pursuant to this Agreement.

Records” shall have the meaning assigned to such term in Section 2.1(i).

Release” means any release, disposal, spilling, leaking, pouring, emission, emptying, discharge, injection, escape, transmission, leaching, or dumping, or any threatened release, of any Hazardous Substances from, or related in any way to, the use, ownership, or operation of the Properties that has not been remedied in accordance with all Applicable Environmental Laws.

Representatives” shall have the meaning assigned to such term in Section 12.4(b).

Required Consent” means a consent by a third party that (i) must be obtained in order for the Conveyance with respect to a Property to be valid and not in violation of the terms of any Lease or Contract, and (ii) if not obtained, will result in a material breach of such Lease or Contract that makes Buyer or Seller liable for a material amount of damages or will entitle the holder of the consent right to terminate the affected Lease or Contract.

Retention Election” shall have the meaning assigned to such term in Section 8.4(a).

Routine Governmental Approvals” means the approvals required to be obtained from Governmental Authorities who are lessors under leases forming a part of the Oil and Gas Properties (or who administer such leases on behalf of such lessors).

SEC” means the Securities Exchange Commission or any successor Governmental Authority.

Securities Act” shall have the meaning assigned to such term in Section 12.5.

Seller Financial Statements” shall have the meaning assigned to such term in Section 12.5.

Seller’s Indemnified Claim” and “Seller’s Indemnified Claims” shall have the meanings assigned to such terms in Section 14.1.

Seller Indemnified Parties” shall have the meaning assigned to such term in Section 14.1.

Seller’s Knowledge” shall mean information actually personally known by the Persons set forth on Schedule 1.1.

 

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Site Assessment” shall have the meaning assigned to such term in Section 7.2.

Surface Rights” shall have the meaning assigned to such term in Section 2.1(f).

Taxes” means all federal, state, local, and foreign income, profits, and franchise taxes, Production Taxes, Property-Related Taxes, Transfer Taxes, and gross receipts, goods and services, capital, transfer, or withholding taxes or other governmental fees or charges imposed by any Governmental Authority, including any interest, penalties, or additional amounts which may be imposed with respect thereto.

Termination Date” shall have the meaning assigned to such term in Section 11.1.

Third Party Claim” shall have the meaning assigned to such term in Section 14.4.

Third Person Transaction” shall have the meaning assigned to such term in Section 7.8.

Transfer Taxes” means any sales, use, stock, stamp, document, real property transfer or gain, filing, recording, registration, and similar Tax or charge, including any interest or penalties thereon.

UGR Unit” means that certain Unit described in and/or formed by that certain Unit Agreement for Fort Trinidad (Upper Glen Rose) Field Unit dated February 12, 1963 as revised, recorded in Volume 386, Page 410 of the Deed Records, Houston County, Texas, and in Volume 148, Page 517 of the Deed Records, Madison County, Texas (the “UGR Unit Agreement”), insofar and only insofar as such Unit covers the Upper Glen Rose formation, to the extent such formation lies within the lateral boundaries of such Unit, both as more particularly described therein. As to any Leases (or portions thereof) lying outside the lateral boundaries of the UGR Unit, for purposes of defining Defensible Title as defined in this Article I, the “Unitized Interval” shall mean the stratigraphic equivalent (as to both the top and base) of the formation described in the UGR Unit Agreement.

Uncompleted Wells” means those Wells for which Seller is currently engaging in drilling and/or completion operations as set forth in Schedule 7.4.

Unit(s)” shall have the meaning assigned to such term in Section 2.1(c).

Wells” shall have the meaning assigned to such term in Section 2.1(b).

Working Interest” means the interest that represents the ownership of the oil and gas leasehold estate created by a Lease and that is burdened with the obligation to bear and pay a percentage of the costs and expenses attributable to the ownership, maintenance, development, and operation of an Oil and Gas Property.

 

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Article II.

Properties to be Sold and Purchased

Section 2.1 Properties. Seller agrees to sell, and Buyer agrees to purchase, for the consideration hereinafter set forth, and subject to the terms and provisions herein contained, the following described properties, assets, rights, and interests:

(a) The undivided Working Interests set forth on Exhibit A, together with any and all other Working Interests, carried interests, reversionary interests (including rights under non-consent provisions), mineral fee interests, possibilities of reverter, royalties, overriding royalties, production payments, net profits interests, and other properties and interests of every kind and character, regardless of whether described on Exhibit A, in, to, under, or derived from the oil and gas leases, oil, gas, and mineral leases, and subleases also described on Exhibit A, and the leasehold estates created thereby (as the same may have been renewed, extended, ratified or amended as of the Closing Date), subject to such depth limitations and other restrictions as may be set forth on Exhibit A or in the instruments that constitute (or are assignments or conveyances in the chain of title to) the foregoing properties and interests, whether producing or non-producing (collectively, the “Leases”), together with each and every kind and character of other right, title, claim, interest, privilege, benefit, and power that Seller has, or that is conferred upon Seller as the owner of such interests, in and to the Leases, the lands covered by the Leases, and the lands pooled, unitized, communitized, or consolidated therewith (such lands covered by the Leases or pooled, unitized, communitized, or consolidated therewith being hereinafter referred to as the “Lands”), even though such right, title, claim, interest, privilege, benefit, or power might be omitted from Exhibit A or incorrectly described on Exhibit A;

(b) The undivided Working Interests set forth on Exhibit B, together with any and all of the same types and categories of other rights, titles, claims, interests, privileges, benefits, and powers referred to in subsection (a), in and to all oil, gas, water, CO2 injection or disposal, and water and salt water injection or disposal wells located on the Lands, whether producing, shut-in, plugged, and/or abandoned, including the wells shown on Exhibit B attached hereto (whether or not located on the Lands) (the “Wells”);

(c) All rights, titles, interests and obligations of Seller in and to, or otherwise derived from, all presently existing and valid oil, gas, and/or mineral unitization, pooling, and/or communitization agreements, declarations, and/or orders (including, without limitation, the UGR Unit and all other units formed under orders, rules, regulations, or other official acts of any Governmental Authority having jurisdiction, and voluntary pooling or unitization agreements, designations, and/or declarations), to the extent that any of the properties described in subsections (a) and (b) above are subject to or bound by such agreements, declarations, or orders, and including all interests of Seller in Hydrocarbon production from any such unit or pool (each, a “Unit” and collectively, the “Units”), whether the Hydrocarbon production from such Units comes from Wells located on or off of a Lease, and all tenements, hereditaments and appurtenances belonging to the Leases and Units;

(d) To the extent transferable or assignable, all rights, titles, and interests of Seller in and to all presently existing and valid production sales, purchase, or exchange contracts, operating agreements, gathering, storage, dehydration, processing, treatment, and transportation agreements, farmout and farmin agreements, unitization, pooling, and communitization

 

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agreements, purchase and sale agreements, exploration agreements, participation agreements, joint development agreements, partnership agreements, joint venture agreements, joint operating agreements, area of mutual interest agreements, saltwater, water, and waste injection, disposal, and transportation agreements, and all other contracts, agreements, and rights owned by Seller, in whole or in part, or to which Seller is a party, to the extent that they are (i) appurtenant to or affect any of the properties described in subsections (a), (b), and (c) above, (ii) used or held for use in connection with the ownership, development, maintenance, or operation thereof, or the gathering, treatment, storage, processing, transportation, and marketing of Hydrocarbons produced therefrom or allocable thereto or (iii) binding on any of the properties described in subsections (a), (b) and (c) above, including those Contracts described on Exhibit C (collectively the “Contracts”); provided, however, that the Contracts shall not include (x) any Leases, (y) any master service agreements or (z) any contracts, agreements, and instruments to the extent that the transfer thereof is (i) restricted by their respective terms, or the necessary Required Consents are not obtained pursuant to Section 7.5, or (ii) subject to the payment of a fee or other consideration under any license agreement or other agreement with a Person other than an Affiliate of Seller for which Buyer would be obligated if such license or other agreement were assigned;

(e) All rights, titles, and interests of Seller in and to all materials, supplies, machinery, equipment, facilities, improvements, and other personal property and fixtures, including wellhead equipment, pumping units, flowlines, tanks, buildings, water and salt water injection facilities, water and saltwater disposal facilities, compression facilities, gathering systems, pipelines, and other equipment located on, appurtenant to, or used in connection with the properties described in subsections (a), (b) and (c) above;

(f) All rights, titles, and interests of Seller in and to all rights-of-way, easements, surface leases, licenses, surface use permits and agreements, and servitudes appurtenant to or used in connection with the properties described in subsections (a), (b), and (c) (collectively, “Surface Rights”), including those Surface Rights described on Exhibit D;

(g) To the extent transferable without the payment of a fee or other consideration (unless Buyer agrees in writing to pay the same), all rights, titles, and interests of Seller in and to all Permits of any nature owned or held by Seller in connection with the properties described in subsections (a), (b) and (c) above;

(h) All Hydrocarbons in, on, under, and produced from or attributable to the properties described in subsections (a), (b) and (c) above from and after the Effective Time and the proceeds thereof;

(i) To the extent the same are related to the items described in this Section 2.1, all title opinions, abstracts of title, title curative, division of interest statements, and all other files, records, and data (including electronic data), including lease files, land files, well files, contract files, division order files, title files, operations, environmental, engineering, and production files, maps, accounting records, correspondence files, marketing files, regulatory compliance files, safety, testing, and inspection records, Tax records (excluding all income Tax returns), and other information in the possession of Seller or copies thereof and all rights relating thereto; but excluding (1) any books, records, data, files, maps, and accounting records to the extent disclosure or transfer is restricted by third-party agreement or applicable Law and the

 

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necessary Required Consents are not obtained pursuant to Section 7.5, or is subject to payment of a fee or other consideration by any license agreement or other agreement with a Person other than an Affiliate of Seller, or by applicable Law, and for which Buyer has not agreed in writing to pay the fee or other consideration, as applicable; (2) all legal records and legal files of Seller, work product of Seller’s legal counsel, communications between Seller’s counsel and Seller and/or Seller’s members (whether or not privileged), and records protected by the attorney-client privilege, other than title opinions; and (3) records relating to the offer, negotiation, or consummation of the sale of the Oil and Gas Properties (collectively, subject to such exclusions, the “Records”); provided, however, that Seller may retain the originals of such Records as Seller has determined may be required for litigation, Tax, accounting, corporate, or auditing purposes and shall instead provide Buyer with copies of such retained Records;

(j) All Hydrocarbons produced from or attributable to the Oil and Gas Properties in storage as of the Effective Time, only to the extent that Seller receives an upward adjustment to the Base Purchase Price pursuant to Section 13.1 in respect of such Hydrocarbons; and

(k) All geophysical and geological data, engineering and consulting reports, computer data, seismic data (including raw data and any interpretative data or information relating to such geologic, geophysical, and seismic data), and other proprietary data (in each case, whether in written or electronic format) owned and possessed by Seller, together with any rights of Seller to such types of intellectual property owned or prepared by third parties and not subject to (i) confidentiality obligations in favor of non-Affiliate third Persons, (ii) Required Consents, restrictions in Seller’s licenses and agreements that require Seller to make payments (which Buyer agrees in writing to pay) or incur other obligations or liabilities upon a transfer, or other contractual restrictions on transferability, unless such restrictions are satisfied, obtained, or waived prior to the Closing, or (iii) licensing arrangements requiring the purchase of a proprietary license by each successor-user, in each case to the extent relating exclusively to the properties described in subsections (a), (b), and (c) above.

The properties, rights and interests specified in the foregoing subsections (a), (b) and (c), except for the Excluded Properties, as defined below, are herein sometimes collectively called the “Oil and Gas Properties,” and the properties, rights and interests specified in the foregoing subsections (a), (b), (c), (d), (e), (f), (g), (h), (i), (j), and (k), except for the Excluded Properties, are herein sometimes collectively called the “Properties”.

Section 2.2 Excluded Properties. The Properties do not include, and there is hereby expressly excepted and excluded therefrom and reserved to Seller:

(a) All rights and choses in action, arising, occurring, or existing in favor of Seller prior to the Effective Time or arising out of the ownership, development, maintenance, or operation of, or the production of Hydrocarbons from, the Oil and Gas Properties prior to the Effective Time (including any and all contract rights, claims, receivables, revenues, recoupment rights, recovery rights, accounting adjustments, mispayments, erroneous payments, or other claims of any nature in favor of Seller and relating and accruing to any time period prior to the Effective Time);

 

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(b) Properties excluded from the purchase and sale contemplated by this Agreement under Section 8.5(b) or Section 7.5;

(c) All Hydrocarbons in, on, under, and produced from or attributable to the Wells prior to the Effective Time and the proceeds thereof, except for the Hydrocarbons described in Section 2.1(j);

(d) Except to the extent constituting funds held in suspense by Seller, all deposits, cash, credits, checks, funds, and accounts receivable attributable to Seller’s interests in the Properties with respect to any period of time prior to the Effective Time;

(e) All rights under that certain Purchase and Sale Agreement executed March 8, 2012 by and between Newfield Exploration Company and Seller (264646-PSA-003) and that certain Asset Purchase Agreement dated November 7, 2012, by and between Canyon Midstream Partners, LLC and Seller;

(f) Any geophysical and geological data, engineering and consulting reports, computer data, seismic data (including raw data and any interpretative data or information relating to such geologic, geophysical, and seismic data), or other proprietary data (in each case, whether in written or electronic format) that either (i) Seller may not assign or transfer under its existing agreements and licenses due to confidentiality obligations, or without obtaining a Required Consent, or making any additional payments which Buyer has not agreed in writing to pay, or incurring other liabilities or obligations, or that are subject to other restrictions on transferability, in each case, that are not satisfied, obtained, or waived prior to the Closing, or (ii) require the purchase of a proprietary license by a successor-user; and

(g) All computer or communications software or intellectual property (including tapes, data, and program documentation and all tangible manifestations and technical information relating thereto) owned, licensed, or used by Seller.

These excluded properties, rights, and interests are collectively referred to as the “Excluded Properties.” It is understood that certain of the Excluded Properties may not be embraced by the term “Properties.” The fact that certain assets have been expressly excluded is not intended to suggest that, had they not been excluded, they would have constituted Properties and shall not be used to interpret the meaning of any word or phrase used in describing the Properties.

Article III.

Purchase Price

Section 3.1 Purchase Price. The purchase price for the Properties shall be SEVEN HUNDRED FIFTEEN MILLION AND NO/100 DOLLARS ($715,000,000.00) (such amount, unadjusted by any adjustments provided for in this Agreement or agreed to by the Parties, being herein called the “Base Purchase Price”). The Base Purchase Price shall be adjusted as provided herein (the Base Purchase Price, as so adjusted, and as the same may otherwise be adjusted by mutual agreement of the Parties, being herein called the “Purchase Price”). Buyer shall pay to Seller, at the Closing, the Purchase Price in immediately available funds, by wire transfer to an account designated by Seller in writing.

 

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Section 3.2 Allocated Values. For purposes of calculating adjustments to the Base Purchase Price under Section 13.1 and notices to the holders of preferential purchase rights (if any), the Parties have agreed upon an allocation of the Base Purchase Price, prior to any adjustments thereto, among the Properties as set forth on Schedule 3.2 (for each Oil and Gas Property, its “Allocated Value”). On or before the Closing Date, Buyer and Seller will agree upon an allocation of the Purchase Price among each of the Properties, in compliance with the principles of Section 1060 of the Internal Revenue Code of 1986, as amended (the “Code”), and the Treasury regulations thereunder, based upon the Allocated Value for each Oil and Gas Property. In determining the allocation of the Purchase Price among the Properties for purposes of Section 1060 of the Code, any adjustments to the Base Purchase Price other than the adjustments provided for in Section 13.1(a)(iv) and Sections 13.1(b)(ii), (iii), (iv) and (v) shall be applied on a pro rata basis to the Allocated Values for all Properties. After all such adjustments are made, any adjustments to the Base Purchase Price pursuant to Section 13.1(a)(iv) and Sections 13.1(b)(ii), (iii), (iv) and (v) shall be applied to the Allocated Values for the particular affected Property(ies). After Seller and Buyer have agreed on the adjustments to the Base Purchase Price and the resulting allocation of the Purchase Price (reflecting the application of such adjustments as provided in this Section 3.2) among the Properties for purposes of Section 1060 of the Code, Seller will be deemed to have accepted such allocation for purposes of this Agreement and the transactions contemplated hereby, but otherwise makes no representation or warranty as to the accuracy thereof. Seller and Buyer agree that (i) the allocation of the Purchase Price (reflecting the application of the adjustments thereto provided for in this Section 3.2) shall be used by Seller and Buyer as the basis for reporting asset values and other items for purposes of all federal, state, and local Tax returns, including Internal Revenue Service Form 8594, and (ii) neither the Parties nor their Affiliates will take positions inconsistent with such allocation in notices to Governmental Authorities, in audit or other proceedings with respect to Taxes, or in other documents or notices relating to the transactions contemplated by this Agreement without the consent of the other Party. Seller and Buyer further agree that, on or before the Closing Date, they will mutually agree as to the further allocation of the Purchase Price (reflecting the application of the adjustments thereto provided for in this Section 3.2) as to the relative portions of such allocations attributable to leasehold costs and depreciable equipment.

Article IV.

Representations of Seller

Seller represents to Buyer that:

Section 4.1 Formation and Qualification. Seller is a limited liability company duly formed, validly existing, and in good standing under the Laws of the State of Delaware and is qualified to do business and in good standing under the Laws of each of the states in which Seller is required to be qualified to do business in order to own and operate the Properties.

Section 4.2 Power and Authority. Seller has full power and authority to enter into and perform its obligations under this Agreement and each other agreement, instrument, or document executed or to be executed by Seller in connection with the transactions contemplated hereby to which it is a party and to consummate the transactions contemplated hereunder. The execution, delivery, and performance by Seller of this Agreement and each other agreement, instrument, or document executed or to be executed by Seller in connection with the transactions contemplated hereby, and the consummation by it of the transactions contemplated hereby and thereby, have been duly authorized by all necessary limited liability company action of Seller.

 

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Section 4.3 Valid, Binding, and Enforceable. This Agreement constitutes (and each other agreement, instrument, or document executed or to be executed by Seller in connection with the transactions contemplated hereby, constitutes) the legal, valid, and binding obligation of Seller, enforceable against Seller in accordance with its terms, except as limited by bankruptcy, insolvency, reorganization, moratorium, and other Laws applicable generally to creditor’s rights and as limited by general equitable principles.

Section 4.4 Approvals; Non-Contravention. The execution, delivery, and performance by Seller of this Agreement and the documents executed in connection herewith, and the consummation by Seller of the transactions contemplated hereby and thereby, will not: (a) conflict with or result in a breach of any of the organizational or governing documents of Seller; (b) except as set forth on Schedule 4.4 and except for Seller’s Credit Agreement, which shall be released at Closing, violate, breach, constitute (with or without due notice or lapse of time or both) a material default, or give rise to any lien, encumbrance, or right of termination, cancellation, payment, guaranty, or acceleration under, or require any consent under, any indenture, license, contract, agreement or other instrument or obligation to which Seller is a party or by which the Properties are bound; or (c) except for any filings required by the HSR Act, Routine Governmental Approvals, and filings, Permits, authorizations, or consents that are customarily obtained after the Closing, violate any order, writ, injunction, decree, judgment, or Law applicable to Seller or the Properties.

Section 4.5 Royalties. As of the Effective Time, to Seller’s Knowledge, all royalties due under the Leases have been fully, properly and timely paid in compliance with all of the terms and conditions of the applicable Leases, the Contracts, and applicable Law, except for royalties being held in suspense in accordance with applicable Law.

Section 4.6 Litigation. Except as set forth on Schedule 4.6, there are no pending, or to Seller’s Knowledge, threatened suits, actions, or other proceedings for which Seller has received written notice that, would: (i) result in the impairment or loss of title to any material part of the Properties or the impairment of the value thereof; (ii) materially hinder or impede the ownership, development, maintenance, operation, or free enjoyment of the Properties; (iii) seeks to restrain or prohibit, or to obtain substantial damages from the Seller with respect to, any operations on the Properties; or (iv) affect adversely in any material respect the ability of Seller to perform this Agreement or consummate the transactions contemplated herein or in the documents executed in connection herewith.

Section 4.7 Leases. To Seller’s Knowledge, each Lease is in full force and effect. Except as set forth on Schedule 4.7, and except for customary provisions in Leases that would cause a Lease to expire if production in paying quantities is not established during the primary term and continued thereafter: (a) to Seller’s Knowledge, Seller is not in material breach or material default, and there has occurred no event, fact, or circumstance that, with the lapse of time or the giving of notice or both, would constitute such a material breach or material default by Seller with respect to any terms of any Lease; and (b) to Seller’s Knowledge, there are no obligations under any Lease, Contract, or otherwise, or any written demand by any lessor, based on a claim of drainage or otherwise, to drill additional wells on the Leases (other than to comply

 

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with implied covenants or deferred bonus payments due with respect to the Leases). No lessor under any Lease has given or, to Seller’s Knowledge, threatened to give notice of any action to terminate, cancel, rescind, repudiate, or procure a judicial reformation of any Lease or any provision thereof.

Section 4.8 Commitments, Abandonments, or Proposals. As of the date hereof, the Wells described on Exhibit B include all of the Hydrocarbon Wells currently capable of producing Hydrocarbons located on the Leases and the Units, and there are no other currently active or drilling Hydrocarbon wells located on the Leases or the Units. Except as set forth on Schedule 4.8: (a) Seller has not abandoned any of the active Wells, or, since the Effective Time, removed any material items of equipment located on the Oil and Gas Properties, except those replaced by items of materially equal suitability; and (b) to Seller’s Knowledge, (i) all inactive Wells drilled by Seller located on the Oil and Gas Properties have been properly temporarily abandoned or plugged and abandoned in accordance with applicable Laws; and (ii) no proposals are currently outstanding (whether made by Seller or by any other Person) to drill additional wells, or to deepen, plug back, or rework existing wells, or to conduct other operations for which consent is required under the applicable operating agreement, or to conduct any operations other than the normal operation of existing Wells on the Oil and Gas Properties, or to abandon any Wells on the Oil and Gas Properties. In addition, except as set forth on Schedule 4.8, there are no operations on the Properties to which Seller is or was a non-consenting party.

Section 4.9 Preferential Rights; Consents. None of the Oil and Gas Properties is subject to any preferential right to purchase, right of first refusal, right of first offer, or similar right that would be applicable to the purchase and sale contemplated by this Agreement. Except for the requirements of the HSR Act, any Routine Governmental Approvals, the requirements of any maintenance of uniform interest provisions contained in any operating or other agreements, and filings, Permits, authorizations, and consents that are customarily obtained after the Closing, (i) Schedule 4.4 sets forth all Required Consents and (ii) no authorization, Consent, approval, exemption, franchise, Permit, or license of, or filing with, any Governmental Authority is required to authorize, or is otherwise required by any Governmental Authority in connection with, the valid execution and delivery by Seller of this Agreement, the documents executed by Seller in connection herewith, the transfer of the Properties to Buyer, or the performance by Seller of its obligations hereunder or thereunder.

Section 4.10 Payments for Production.

(a) Except as set forth on Schedule 4.10(a), (i) there are no calls on production, options to purchase, or similar rights in effect with respect to any portion of the Hydrocarbons allocable to the Properties. Except as set forth in Schedule 4.10(a), as of the date hereof, to Seller’s Knowledge, Seller is receiving from the purchasers of production all proceeds from the sale of Hydrocarbons attributable to the interests of Seller in the Properties, and no portion of any such proceeds is being held in suspense, subject to a claim for refund by the purchaser, being used as an offset or as collateral for other obligations (whether disputed or undisputed), or otherwise not being paid to Seller as it becomes due in the ordinary course of business.

(b) Except as set forth on Schedule 4.10(b), Seller is not obligated under any contract or agreement containing a take-or-pay, advance payment, prepayment, or similar

 

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provision, under any production payment, deferred production, or similar arrangement, or under any gathering, transportation, or other contract or agreement with respect to any of the Properties to sell, gather, deliver, process, or transport any Hydrocarbons without then or thereafter receiving full payment therefor.

Section 4.11 Contracts.

(a) Schedule 4.11 attached hereto lists:

(i) All contracts affecting the Properties that can reasonably be expected to result in aggregate payments by Seller of more than $300,000 during the current or any subsequent fiscal year or $3,000,000 in the aggregate over the term of such contract (in each case, based solely on the terms thereof and current quantities, if applicable, without regard to any expected increase in quantities or revenues);

(ii) All contracts affecting the Properties that can reasonably be expected to result in aggregate revenues to Seller of more than $300,000 during the current or any subsequent fiscal year or $3,000,000 in the aggregate over the term of such contract (in each case, based solely on the terms thereof and current quantities, if applicable, without regard to any expected increase in quantities or revenues);

(iii) all joint venture agreements, partnership agreements, purchase and sale agreements, dry-hole, acreage or bottom hole contribution agreements, exploration agreements, participation agreements, joint operating agreements, unitization, pooling, and communization agreements (including the UGR Unit Agreement), area of mutual interest agreements, and other similar agreements as to which any terms remain executory and affect any Property (except that Schedule 4.11 may not list certain modifications to joint operating agreements that affect Seller’s interest solely in the Glen Rose B, D or E formations);

(iv) all Hydrocarbon purchase contracts, gathering contracts, processing contracts, transportation contracts, Hydrocarbon marketing contracts, salt water and water disposal or injection contracts and all other marketing-related contracts affecting any Property which are not, by the terms thereof, subject to termination upon thirty (30) days or less notice; and

(v) all farm-out or farm-in agreements and joint development agreements affecting any Oil and Gas Property under which any party thereto is entitled to receive assignments not yet made, or could earn additional assignments after the Effective Time.

All agreements set forth on Schedule 4.11 shall collectively be referred to as the “Property Contracts”.

(b) With respect to the Property Contracts: (i) to Seller’s Knowledge, all Property Contracts identified in clauses (i) and (ii) of Section 4.11(a) are in full force and effect; (ii) to Seller’s Knowledge, Seller is not in material breach or material default, and there has

 

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occurred no event, fact, or circumstance that, with the lapse of time or the giving of notice, or both, would constitute such a material breach or material default by Seller, with respect to the terms of any Property Contract; (iii) to Seller’s Knowledge, no other Person is in material breach or material default with respect to the terms of any Property Contract; and (iv) neither Seller nor, to Seller’s Knowledge, any other party to any Property Contract has given or threatened to give notice of any action to terminate, cancel, rescind, or procure a judicial reformation of any Property Contract or any provision thereof.

Section 4.12 Affiliate Transactions. There are no transactions affecting any of the Properties between Seller and any Affiliate of Seller that will be binding on Buyer or the Properties after the Closing.

Section 4.13 Imbalances. Except for normal pipeline imbalances that are adjusted in kind by the purchasing or transporting pipeline each month, and except for the imbalances described in Schedule 4.13, there are no wellhead imbalances or other imbalances attributable to the Wells.

Section 4.14 Compliance with Laws. Except as disclosed on Schedule 4.14, to the Seller’s Knowledge, the Properties are, and the operation of the Properties has been and currently is, in material compliance with the provisions and requirements of all Laws, and all Permits required under all Laws (excluding Applicable Environmental Laws and Permits under Applicable Environmental Laws, which are addressed in Section 4.15) applicable to the Properties, or the ownership, operation, development, maintenance, or use of any thereof. Seller or, to Seller’s Knowledge, each third Person operator of any of the Wells, as applicable, has all such Permits required under applicable Laws (excluding Applicable Environmental Laws and Permits under Applicable Environmental Laws, which are addressed in Section 4.15) in connection with the ownership and operation of the Wells, except when the failure to obtain or maintain a Permit would not have a Material Adverse Effect, and to Seller’s Knowledge, all of such Permits and filings are in full force and effect. Neither Seller nor, to Seller’s Knowledge, any other Person, has received notice from any Governmental Authority or other Person that any such applicable Law or Permit has, in any material respect, been violated or not complied with by Seller or any other Person.

Section 4.15 Environmental Matters.

(a) Except as set forth in Schedule 4.15, to Seller’s Knowledge, the operations conducted in and on the Wells, the Leases, and the Units by Seller and by any third Person operator have not been and are not in violation of any Applicable Environmental Laws, except for prior instances of violations that have been fully and finally remedied or resolved to the satisfaction of all Governmental Authorities having jurisdiction over such matters.

(b) Except as set forth in Schedule 4.15, to Seller’s Knowledge, the operations conducted in and on the Wells, the Leases and the Units by Seller and by any third Person operator have not been in violation of any material Permit required under Applicable Environmental Laws.

(c) Except as disclosed on Schedule 4.15, Seller has not received any written notice of violation or assessment from any Governmental Authority that alleges that Seller or any

 

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other third person operator is in violation of any Applicable Environmental Law or Permit in connection with operations in and on the Wells, which alleged violation or assessment remains uncured or unresolved. There are no pending or, to Seller’s Knowledge, threatened proceedings, against any Oil and Gas Property, resulting from the violation of any Applicable Environmental Law or Permit, that would reasonably be expected to have a Material Adverse Effect.

(d) To Seller’s Knowledge, there has been no Release under or from any of the Wells in violation of Applicable Environmental Laws or any Permit required under Applicable Environmental Laws, except for prior Releases that (i) have been fully and finally remedied to the satisfaction of all Governmental Authorities having jurisdiction over such matters, or (ii) otherwise would not have a Material Adverse Effect.

(e) Except as set forth on Schedule 4.15, Seller has not entered into any currently effective agreement with any Governmental Authority based on any violation of an Applicable Environmental Law or any Permit or filing pursuant thereto that requires a future payment by, or restricts, affects, impairs, or limits the operation of, the Oil and Gas Properties.

(f) Following the Closing, Buyer shall not be entitled to claim a breach of this Section 4.15 for any violation of Applicable Environmental Laws, environmental liability, or any claim, demand, notice, filing, investigation, administrative proceeding, hearing, action, suit, or other legal proceeding, of which Buyer had actual knowledge prior to the Closing.

Section 4.16 Tax Matters. Except with respect to those Taxes prorated between Seller and Buyer as provided in Section 12.7, during the period of Seller’s ownership of the Properties, Seller has filed in a timely manner all returns it was required to file in connection with all Property-Related Taxes and Production Taxes imposed upon or assessed with respect to, measured by, charged against, or attributable to the Properties or Hydrocarbon production therefrom or allocable thereto and has paid all Property-Related Taxes and Production Taxes shown on such returns as owing that are due or payable. The Properties are not otherwise subject to, for federal income Tax purposes, a partnership among Seller and any other Person for which a partnership income Tax return is required to be filed under Subchapter K of Chapter 1 of Subtitle A of the Code (other than a partnership for which an election to be excluded from such provisions is in effect pursuant to the provisions of Section 761 of the Code and the regulations thereunder).

Section 4.17 Suspense Accounts. Schedule 4.17 contains, as of the date set forth in Schedule 4.17, a true and complete list of all amounts held in suspense by Seller in its capacity as operator of the Wells with respect to Hydrocarbon production from or allocable to such Wells, including the name of the relevant Well, the dollar amount held in suspense, the payee or potential payee with respect thereto, and the reason such amounts are being held in suspense.

Section 4.18 No Brokers. Seller has not engaged any financial advisor, broker, agent, or finder, or incurred any liability, contingent or otherwise, in favor of any other such Person relating to the transactions contemplated by this Agreement for which Buyer will have any responsibility hereunder.

 

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Section 4.19 No Bankruptcy. There are no bankruptcy, insolvency, reorganization, or arrangement proceedings pending, being contemplated by, or to Seller’s Knowledge, threatened against Seller or any Affiliate that controls Seller.

Article V.

Disclaimer

Section 5.1 Disclaimer. THE EXPRESS REPRESENTATIONS AND WARRANTIES OF SELLER CONTAINED IN ARTICLE IV ABOVE AND THE SPECIAL WARRANTY OF TITLE IN THE CONVEYANCE TO BE DELIVERED AT CLOSING ARE EXCLUSIVE AND ARE IN LIEU OF ALL OTHER REPRESENTATIONS AND WARRANTIES, EXPRESS, IMPLIED, STATUTORY, OR OTHERWISE, AND SELLER EXPRESSLY DISCLAIMS, AND BUYER ACKNOWLEDGES THAT IT DOES NOT RELY UPON, ANY AND ALL SUCH OTHER REPRESENTATIONS AND WARRANTIES. OTHER THAN THE EXPRESS REPRESENTATIONS AND WARRANTIES OF SELLER CONTAINED IN ARTICLE IV ABOVE AND THE SPECIAL WARRANTY OF TITLE IN THE CONVEYANCE TO BE DELIVERED AT CLOSING, THE PROPERTIES SHALL BE CONVEYED PURSUANT HERETO WITHOUT, AND BUYER ACKNOWLEDGES THAT IT DOES NOT RELY UPON, ANY WARRANTY OR REPRESENTATION, WHETHER EXPRESS, IMPLIED, STATUTORY, OR OTHERWISE, RELATING TO TITLE, THE CONDITION, QUANTITY, QUALITY, FITNESS FOR A PARTICULAR PURPOSE, CONFORMITY TO THE MODELS OR SAMPLES OF MATERIALS, MERCHANTABILITY OF ANY PERSONAL PROPERTY OR EQUIPMENT, OR ITS FITNESS FOR ANY PURPOSE, AND, EXCEPT AS PROVIDED OTHERWISE IN THE FIRST SENTENCE OF THIS SECTION 5.1, WITHOUT ANY OTHER EXPRESS, IMPLIED, STATUTORY, OR OTHER WARRANTY OR REPRESENTATION WHATSOEVER. BUYER SHALL INSPECT (AND UPON CLOSING, SHALL HAVE INSPECTED OR BE DEEMED TO HAVE WAIVED THE RIGHT TO INSPECT) THE PROPERTIES TO SATISFY ITSELF AS TO THEIR PHYSICAL AND ENVIRONMENTAL CONDITION, BOTH SURFACE AND SUBSURFACE, INCLUDING BUT NOT LIMITED TO CONDITIONS SPECIFICALLY RELATED TO THE PRESENCE, RELEASE, OR DISPOSAL OF HAZARDOUS SUBSTANCES, SOLID WASTES, ASBESTOS AND OTHER MAN-MADE FIBERS, OR NATURALLY OCCURRING RADIOACTIVE MATERIALS (“NORM”). WITH RESPECT TO THE PHYSICAL AND ENVIRONMENTAL CONDITION OF THE PROPERTIES, BUYER IS RELYING SOLELY UPON THE REPRESENTATIONS AND WARRANTIES IN ARTICLE IV AND ITS OWN INSPECTION OF THE PROPERTIES, AND UPON CLOSING, BUYER SHALL ACCEPT ALL OF THE SAME IN THEIR “AS-IS”, “WHERE-IS” CONDITION, EXCEPT AS OTHERWISE PROVIDED IN THIS AGREEMENT. EXCEPT FOR THE REPRESENTATIONS AND WARRANTIES CONTAINED IN ARTICLE IV AND IN THE SPECIAL WARRANTY OF TITLE IN THE CONVEYANCE, SELLER MAKES NO, AND HEREBY DISCLAIMS, AND BUYER ACKNOWLEDGES THAT IT DOES NOT RELY UPON, ANY WARRANTY OR REPRESENTATION, EXPRESS, IMPLIED, STATUTORY, OR OTHERWISE, AS TO THE ACCURACY OR COMPLETENESS OF ANY DATA, REPORTS, RECORDS, PROJECTIONS, INFORMATION, OR MATERIALS NOW, HERETOFORE, OR HEREAFTER FURNISHED OR MADE AVAILABLE TO BUYER IN CONNECTION WITH THIS AGREEMENT OR BUYER’S DUE DILIGENCE REVIEW, INCLUDING, WITHOUT LIMITATION, INFORMATION RELATIVE TO PRICING ASSUMPTIONS, OR QUALITY OR QUANTITY OF HYDROCARBON RESERVES (IF

 

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ANY) ATTRIBUTABLE TO THE PROPERTIES, OR THE ABILITY OR POTENTIAL OF THE PROPERTIES TO PRODUCE HYDROCARBONS, OR THE ENVIRONMENTAL CONDITION OF THE PROPERTIES, OR ANY OTHER MATTERS CONTAINED IN ANY MATERIALS FURNISHED OR MADE AVAILABLE TO BUYER BY SELLER OR BY SELLER’S AGENTS OR REPRESENTATIVES. ANY AND ALL SUCH DATA, RECORDS, REPORTS, PROJECTIONS, INFORMATION, AND OTHER MATERIALS (WRITTEN OR ORAL) FURNISHED BY SELLER OR OTHERWISE MADE AVAILABLE OR DISCLOSED TO BUYER ARE PROVIDED TO BUYER AS A CONVENIENCE AND SHALL NOT CREATE OR GIVE RISE TO ANY LIABILITY OF OR AGAINST SELLER, AND ANY RELIANCE ON OR USE OF THE SAME SHALL BE AT BUYER’S SOLE RISK TO THE MAXIMUM EXTENT PERMITTED BY LAW.

Article VI.

Representations of Buyer

Buyer represents to Seller that:

Section 6.1 Formation and Qualification. Buyer is a limited liability company, duly formed and validly existing and in good standing under the Laws of the State of Delaware and is qualified to do business and in good standing under the Laws of the State of Texas. Buyer is also qualified to own and operate the Oil and Gas Properties with all applicable Governmental Authorities having jurisdiction over the Properties, to the extent such qualification is necessary or will be necessary upon the consummation of the transactions contemplated hereby (including Buyer has met all bonding requirements of such Governmental Authorities).

Section 6.2 Power and Authority. Buyer has full power and authority to enter into and perform its obligations under this Agreement and each other agreement, instrument, or document executed or to be executed by Buyer in connection with the transactions contemplated hereby and to consummate the transactions contemplated hereunder and thereunder. The execution, delivery, and performance by Buyer of this Agreement and each other agreement, instrument, or document executed or to be executed by Buyer in connection with the transactions contemplated hereby and thereby, and the consummation by it of the transactions contemplated hereby and thereby, have been duly authorized by all necessary limited liability company action of Buyer.

Section 6.3 Approvals; Non-Contravention. The execution, delivery, and performance by Buyer of this Agreement and the documents executed in connection herewith, and the consummation of the transactions contemplated hereby and thereby, will not: (a) conflict with or result in a breach of any of the organizational or governing documents of Buyer; (b) result in the creation of any lien or other encumbrance against any of Buyer’s property; (c) except for (i) requirements (if any) that there be obtained consents to assignment from third parties, and (ii) Routine Governmental Approvals, result in any default under any agreement or instrument to which Buyer is a party; or (iii) violate any order, writ, injunction, decree, judgment, or Law applicable to Buyer.

Section 6.4 Valid, Binding, and Enforceable. This Agreement constitutes (and each other agreement, instrument, or document executed or to be executed by Buyer in connection with the transactions contemplated hereby, constitutes) the legal, valid, and binding obligation of

 

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Buyer, enforceable against Buyer in accordance with its terms, except as limited by bankruptcy, insolvency, reorganization, moratorium, and other Laws applicable generally to creditor’s rights and as limited by general equitable principles.

Section 6.5 No Litigation. There are no pending suits, actions, or other proceedings (including bankruptcy, insolvency, or receivership proceedings) in which Buyer is a party (or, to Buyer’s knowledge, which have been threatened to be instituted against Buyer) which affect adversely the execution and delivery of this Agreement or the consummation of the transactions contemplated hereby or in the documents executed in connection herewith.

Section 6.6 Governmental and Third Person Consents. Except for the requirements of the HSR Act, Routine Governmental Approvals, and filings, Permits, authorizations, and consents that are customarily obtained after the Closing, no authorization, consent, approval, exemption, franchise, Permit, or license of, or filing with, any Governmental Authority or any other Person is required to authorize, or is otherwise required in connection with, the valid execution and delivery by Buyer of this Agreement or the documents executed in connection herewith or the performance by Buyer of its obligations hereunder or thereunder.

Section 6.7 No Brokers. Buyer has not engaged any financial advisor, broker, agent, or finder, or incurred any liability, contingent or otherwise, in favor of any other such Person relating to the transactions contemplated by this Agreement for which Seller will have any responsibility hereunder.

Section 6.8 No Bankruptcy. There are no bankruptcy, insolvency, reorganization, or arrangement proceedings pending, being contemplated by, or to Buyer’s knowledge, threatened against Buyer or any Affiliate that controls Buyer.

Section 6.9 No Distribution. Buyer is acquiring the Properties for its own account, for investment, and not with the intent to make, or to offer or resell in connection with, a distribution in violation of the Securities Act of 1933 as amended (and the rules and regulations promulgated thereunder) or a distribution in violation of any other applicable securities Laws.

Section 6.10 Knowledge and Experience. Buyer has (and had, prior to negotiations regarding the Properties) such knowledge and experience in the ownership and operation of oil and gas properties and financial and business matters as to be able to evaluate the merits and risks of an investment in the Properties. Buyer is able to bear the risks of an investment in the Properties and understands the risks of, and other considerations relating to, a purchase of the Properties.

Section 6.11 Opportunity to Verify Information. As of the Closing, Buyer has been furnished with all materials relating to the Properties requested by Buyer and has been afforded the opportunity to ask questions of Seller (or a Person or Persons acting on Seller’s behalf) concerning the Properties. Prior to the Closing, Buyer has received all materials, documents, and other information relating to the Properties that Buyer deems necessary to evaluate the Properties and understand the merits and risks of an investment in the Properties. Buyer has made its own independent investigation of the Properties to the extent necessary to verify the truth and accuracy of such materials, documents, and other information. At the Closing, Buyer shall be deemed to have knowledge of all facts contained in all materials, documents, and other information which Buyer has been furnished or to which Buyer has been given access.

 

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Section 6.12 Merits and Risks of an Investment in the Properties. Buyer understands and acknowledges that: (a) an investment in the Properties involves certain risks, including, without limitation, risks relative to pricing assumptions, the quality or quantity of Hydrocarbon reserves attributable to the Properties, or the ability or potential of the Properties to produce Hydrocarbons; (b) neither the SEC nor any other Governmental Authority has passed upon the Properties or made any finding or determination as to the fairness of an investment in the Properties or the accuracy or adequacy of the disclosures made to Buyer; (c) except as set forth in Section 9.1, Buyer is not entitled to cancel, terminate, or revoke this Agreement; and (d) except for the express representations, warranties, covenants, and remedies provided in this Agreement and the special warranty of title contained in the Conveyance, Buyer is acquiring the Properties on an “as-is, where-is” basis with all faults, and has not relied upon any other representations, warranties, covenants, or statements of Seller in entering into this Agreement.

Article VII.

Certain Covenants

Section 7.1 Access to Records. Seller will give Buyer, or Buyer’s authorized representatives, at Seller’s offices and at all reasonable times before the Closing Date, access to Seller’s Records pertaining to the ownership, development, maintenance, and operation of the Properties to the extent requested by Buyer, for the purpose of conducting the due diligence reviews contemplated by Section 8.1 below. Buyer may make copies of such Records, at its expense, but shall return all copies so made if the Closing does not occur. All costs of copying such items shall be borne by Buyer. Seller shall not be obligated to provide Buyer and its representatives with access to any Records which Seller cannot provide to Buyer and its representatives without, in its reasonable opinion, breaching confidentiality agreements or other agreements with other parties. If Seller fails to provide any Records because of any such confidentiality or other agreements, Seller shall identify, in writing, the information not provided, to the extent it may do so without violating such agreement, and identify the Person or Persons whose consent is necessary in order for Seller to disclose such Records.

Section 7.2 Physical Inspection. Subject to applicable contracts, Seller shall provide, or with respect to Properties not operated by Seller, shall request the third Person operators to provide, to Buyer or Buyer’s authorized representatives, at all reasonable times before the Closing Date and upon reasonable notice to Seller, physical access to the Oil and Gas Properties for the purpose of inspecting same. Buyer agrees to comply fully with the rules, regulations, and instructions issued by Seller (or third Person operators) regarding the actions of Buyer while upon, entering, or leaving the Properties. Buyer’s environmental investigation of the Properties shall be limited to conducting a Phase I Environmental Site Assessment in accordance with the American Society for Testing and Materials (A.S.T.M.) Standard Practice Environmental Site Assessments: Phase I Environmental Site Assessment Process (Publication Designation: E1527-05), and additional testing and sampling of air, soil, and water (“Additional Testing”) if, in the professional judgment of Buyer’s environmental consultant reasonably exercised, such Additional Testing is necessary to determine whether there exists a Defect in the nature of a violation of Applicable Environmental Laws or a material breach of the representation and warranty in Section 4.15 (“Site Assessment”); provided, however, that Buyer shall provide to

 

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Seller written notice concerning whether Buyer intends to conduct any Additional Testing (“Additional Testing Notice”) no later than July 3, 2014. The failure of Buyer to deliver the Additional Testing Notice to Seller on or prior to July 3, 2014, shall constitute an election by Buyer not to conduct any such Additional Testing. To the extent Buyer delivers to Seller a timely Additional Testing Notice, Buyer’s rights to perform any Additional Testing shall be limited to the specific items set forth in the Additional Testing Notice. Buyer shall provide to Seller at least forty-eight (48) hours’ notice in advance of the performance of any work related to a Site Assessment (including complete particulars regarding any Additional Testing to be conducted), and Seller or Seller’s representatives shall be entitled to observe all such Site Assessment-related work (including any Additional Testing). Buyer shall furnish to Seller, at Buyer’s cost and expense, a copy of any written report prepared by Buyer’s environmental consultant related to any Site Assessment of the Properties (including any Additional Testing) as soon as reasonably possible after it is prepared. Seller shall not be deemed, by its receipt of any environmental reports, documents or otherwise, to have made any representation or warranty, expressed, implied, or statutory, in addition to the representations and warranties set forth in Article IV as to the condition of the Properties or the accuracy of said environmental reports, documents, or the information contained therein. All environmental reports prepared by or for Buyer related to the Properties shall constitute “Confidential Information” subject to the terms of the Confidentiality Agreement. In addition, all Parties agree to engage environmental consultants in a manner that maximizes confidentiality under this Section 7.2.

Section 7.3 Exculpation and Indemnification. If Buyer exercises rights of access under this Article VII or otherwise, or conducts examinations or inspections under this Article VII or otherwise, then: (a) such access, examination, and inspection shall be at Buyer’s sole risk, cost, and expense (including any risks associated with any physical condition of the Properties that may impair access), and Buyer waives and releases all claims against the Seller Indemnified Parties arising in any way therefrom or in any way related thereto or arising in connection with the conduct of any Seller Indemnified Party in connection therewith; and (b) Buyer shall indemnify, defend, and hold harmless the Seller Indemnified Parties from any and all claims, actions, causes of action, liabilities, losses, damages, fines, penalties, costs, or expenses (including court costs and consultants’ and reasonable attorneys’ fees) of any kind or character, or liens or encumbrances for labor or materials, arising out of or in any way connected with such matters. THE FOREGOING RELEASE AND INDEMNIFICATION SHALL APPLY WHETHER SUCH CLAIMS, ACTIONS, CAUSES OF ACTION, LIABILITIES, DAMAGES, LOSSES, COSTS OR EXPENSES ARISE OUT OF (i) THE NEGLIGENCE (INCLUDING SOLE NEGLIGENCE, SIMPLE NEGLIGENCE, CONCURRENT NEGLIGENCE, OR ACTIVE OR PASSIVE NEGLIGENCE) OF ANY BUYER INDEMNIFIED PARTY OR ANY SELLER INDEMNIFIED PARTY, AS APPLICABLE, OR (ii) STRICT LIABILITY; PROVIDED, HOWEVER THAT THE FOREGOING RELEASE AND INDEMNIFICATION SHALL NOT APPLY TO OR INCLUDE CLAIMS, ACTIONS, CAUSES OF ACTION, LIABILITIES, DAMAGES, LOSSES, COSTS, OR EXPENSES CAUSED BY THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF ANY SELLER INDEMNIFIED PARTY.

Section 7.4 Interim Operation. Prior to the Closing, except for the drilling and completion operations for the Uncompleted Wells as described on Schedule 7.4, Seller will continue the operation of the Oil and Gas Properties in the ordinary course of business (or, where Seller is not the operator of a Property, Seller will continue actions as a non-operator in the

 

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ordinary course of business), and will: (a) not sell, transfer, convey, mortgage, pledge, encumber, or otherwise dispose of (or enter into any contract to do the same, or permit any Affiliate of Seller to do any of the foregoing) any portion of the Properties, except for Permitted Encumbrances and sales or other dispositions of (i) Hydrocarbons in the ordinary course of business after production, or (ii) equipment and other personal property or fixtures in the ordinary course of business where the same is replaced by an item or items of at least equal suitability, or is otherwise no longer necessary for the operation of the Properties; (b) pay, when due, Seller’s share of all Taxes, costs, expenses, and other obligations relating to the Properties, and keep the Properties free of liens that do not constitute Permitted Encumbrances; (c) maintain in effect insurance with respect to the ownership, development, maintenance, and operation of the Properties, providing the same types of coverage, in the same amounts, and with the same deductibles, as the insurance maintained in effect by Seller on the date of this Agreement; and (d) perform all of the material obligations of Seller under the Leases and the Contracts, including the payment in a timely and proper manner of royalties, overriding royalties, and other lease burdens, delay rentals, shut-in wells payments, and other lease maintenance payments, and other amounts due in respect thereof. Between the date hereof and the Closing Date, should Seller receive (or desire to make) any proposal to drill additional wells, or plug and abandon any wells, on the Oil and Gas Properties, or to conduct other operations which require the consent of the non-operators under the applicable operating agreement, pooling order, or other agreement, Seller will notify Buyer of, and consult with Buyer concerning, such proposals, but any decision with respect to proposals shall be made by Seller in its sole discretion, so long as the decisions are made in the ordinary course of business and do not adversely affect the value of the Properties; provided, however, without Buyer’s prior written consent, Seller shall not (i) commit to perform, or participate in, additional drilling operations on the Oil and Gas Properties that deviate materially (in terms of numbers of Hydrocarbon wells or estimated costs to drill and complete) from the drilling program set forth in Schedule 7.4; (ii) commit to the abandonment of any Well; (iii) agree to amend, modify, release, terminate, extend, or abandon any Lease, Contract, or other property or asset included in the Properties; or (iv) enter into any new contractual obligation relating to any Property having a duration longer than thirty (30) days or estimated to require an expenditure greater than $250,000, net to the interest of Seller. Seller shall also provide to Buyer, within five (5) days after receipt thereof, copies of all correspondence (x) from any Governmental Authority relating to the Properties, or (y) evidencing any claim or demand against Seller, or the commencement of any suit, action, or proceeding against Seller before any court or Governmental Authority that relates to the Properties. Without expanding any obligations which Seller may have to Buyer, it is expressly agreed that Seller shall not have any liability to Buyer with respect to the operation of a Property greater than that which it might have as the operator to a non-operator under the applicable operating agreement (or, in the absence of such an operating agreement, under the AAPL 610 (1989 Revision) Model Form Operating Agreement), AND SELLER OR OPERATOR SHALL NOT BE RESPONSIBLE TO BUYER FOR SELLER’S OR OPERATOR’S NEGLIGENCE, AND BUYER ACKNOWLEDGES THAT NEITHER SELLER NOR OPERATOR HAVE ANY RESPONSIBILITY TO BUYER FOR THEIR ACTIONS, OTHER THAN FOR SELLER’S GROSS NEGLIGENCE OR WILLFUL MISCONDUCT.

Section 7.5 Consents.

(a) Upon the execution of this Agreement, Seller will send each holder of a right to consent to assignment pertaining to a Property (“Consent”) known to Seller a notice

 

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seeking such holder’s consent to the Conveyance pertaining to the relevant Property and the transactions contemplated hereby, including any Required Consents, but excluding any Routine Governmental Approvals. Seller will thereafter use its commercially reasonable efforts to cause all applicable Consents, including Required Consents, to be obtained and delivered on or before the Closing Date. Buyer will use reasonable commercial efforts to provide any reasonable assistance requested by Seller to ensure that all remaining consents are promptly granted.

(b) If, as of the Closing Date, a holder of a Required Consent has not yet delivered such Required Consent and the time for granting such Required Consent has not expired, then the Properties covered by that Required Consent will not be conveyed to Buyer at the Closing, and the Base Purchase Price will be reduced by the Allocated Value of the interest in the Properties subject to such Required Consent. If Properties have been excluded from the Properties conveyed to Buyer at the Closing due to a failure to obtain a Required Consent, and if the relevant Required Consent is received or deemed received to the reasonable satisfaction of Buyer pursuant to the terms of the underlying agreement on or before six (6) months after the Closing Date, Seller shall so notify Buyer, and within fifteen (15) days after Buyer’s receipt of such notice, Seller shall assign and convey to Buyer, and Buyer shall purchase and accept from Seller, the Properties affected by such Required Consent pursuant to an instrument of conveyance substantially in the form of the Conveyance and subject to the terms of this Agreement (including all the representations, warranties, covenants, and indemnities hereof), and Buyer shall pay to Seller an amount equal to the Allocated Value of such Property, subject to adjustments in accordance with this Agreement. If Seller does not receive a Required Consent affecting a Property excluded from the Closing within six (6) months after the Closing Date, the affected Property shall become an Excluded Property and cease to be subject to the terms of this Agreement, and the Base Purchase Price shall be deemed to have been permanently reduced by the Allocated Value of such Property.

Section 7.6 Operatorship. Seller makes no representation and does not warrant or guarantee that Buyer will succeed in being appointed successor operator of any Property. At and as of the Closing Date, Seller shall resign as operator of the Wells. With respect to those Wells as to which Seller owns a sufficient share of the Working Interest to control the selection of the successor operator, at the Closing, Seller shall deliver to Buyer a written notification designating Buyer as the successor operator of such Wells, effective as of the Closing Date. With respect to those Wells (if any) as to which Seller does not own a sufficient share of the Working Interest to control the selection of the successor operator, Seller will cast its vote, and will execute mutually satisfactory letters prepared by Buyer requesting the votes of the other owners of Working Interests in the relevant Wells, in each case in favor of the designation of Buyer as successor operator of such Wells, effective as of the Closing Date. Buyer shall, promptly following the Closing (or earlier to the extent provided under Section 17.14), file all appropriate or required forms, Permit transfers, and declarations or bonds with all Governmental Authorities having jurisdiction relative to its assumption of operatorship. For all Oil and Gas Properties operated by Seller, at the Closing, Seller shall execute and deliver to Buyer, on forms to be prepared by Buyer and acceptable to Seller, and Buyer shall promptly file, Railroad Commission of Texas Forms P-4 transferring regulatory responsibility for the operatorship of such Oil and Gas Properties to Buyer. In each case, Seller shall use reasonable commercial efforts to assist Buyer in assuming the timely operation of the Wells operated by Seller prior to the Closing.

 

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Section 7.7 HSR Act. If the HSR Act applies to the transactions contemplated in this Agreement, then within fifteen (15) days after the date of execution hereof, Seller and Buyer shall file appropriate Notification and Report Forms under the HSR Act with respect to this Agreement and the transactions contemplated herein. Seller and Buyer shall cooperate to coordinate such filings and shall make reasonable commercial efforts to respond to any request or inquiry of any Governmental Authority with respect thereto. Seller and Buyer shall request early termination of the waiting period under the HSR Act upon the filing of the Notification and Report Forms.

Section 7.8 Exclusivity. Between the date of execution hereof and the earlier of the Closing Date or the termination of this Agreement pursuant to Section 11.1 (the “Exclusive Period”), neither Seller nor any member of Seller shall, directly or indirectly, through any officer, director, manager, employee, Affiliate, attorney, financial advisor, or other agent or representative, take any action to solicit, initiate, seek, or encourage any inquiry, proposal, or offer from, furnish any information to, or participate in any discussions or negotiations with, any Person other than Buyer or an Affiliate thereof regarding any direct or indirect acquisition of any portion of the Properties (a “Third Person Transaction”). In no event will Seller accept or enter into an agreement concerning any Third Person Transaction during the Exclusive Period.

Article VIII.

Due Diligence Review

Section 8.1 Review By Buyer. Should, as a result of Buyer’s examinations and investigations, or otherwise, one or more matters come to Buyer’s attention which would constitute a Defect (as defined below), and should there be one or more of such Defects which Buyer is unwilling to waive, Buyer shall notify Seller in writing of such Defects as soon as the same are identified by Buyer, but in no event later than five (5) Business Days before the Closing Date (“Defect Deadline”). Such Defects as to which Buyer provides notice are herein called “Asserted Defects”. Such notification shall include, for each Asserted Defect, to the extent applicable: (i) if the Asserted Defect relates to title to an Oil and Gas Property, a description of the Asserted Defect and the Oil and Gas Property listed on Exhibit A or B to which it relates and supporting documentation or information reasonably necessary to fully describe the basis for the Defect, the size of any variance in “Net Revenue Interest”, “Working Interest”, or “Net Leasehold Acres” which does or would result from such Asserted Defect, and the amount by which Buyer would propose to adjust the Base Purchase Price, which amount shall not exceed the Allocated Value of the Oil and Gas Properties affected by such Asserted Defect; and (ii) if the Defect relates to Applicable Environmental Laws, a description of the affected Property, a description of the specific matter constituting a violation of Applicable Environmental Laws or a material breach of the representation and warranty set forth in any of Section 4.15(a), Section 4.15(b), Section 4.15(c), or Section 4.15(d) with respect to such Property, and an estimate of the Lowest Cost Response to cure or remedy the matter. All Defects with respect to which Buyer fails to so give Seller notice by the Defect Deadline will be deemed waived for all purposes. Except for Seller’s indemnity obligation under Section 14.2 as it relates to a breach of the representations and warranties set forth in Section 4.7 (other than the first sentence of Section 4.7) and in Section 4.15, Buyer’s sole and exclusive rights and remedies with respect to any matter that constitutes an Asserted Defect shall be those set forth in this Article VIII, and Buyer shall not be entitled to refuse to close or to any right or remedy with respect to any Asserted Defect, except as provided in this Article VIII. To the extent that, prior to the

 

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Defect Deadline, Buyer has knowledge of a Defect that constitutes a breach of the representations and warranties in Section 4.7 or Section 4.15 and does not provide notice of such Defect in accordance with this Section 8.1, Buyer shall not be entitled to any of the remedies set forth in Article XIV of this Agreement. All access to Seller’s Records and the Properties in connection with such due diligence shall be subject and pursuant to Sections 7.1 and 7.2 (including, without limitation, the exculpation and indemnification provisions contained in Section 7.3).

Section 8.2 Nature of Defects. The term “Defect”, as used in this Agreement, shall mean (i) with respect to the title to a Property, any lien, encumbrance, obligation, or defect in title that causes Seller’s title to any Oil and Gas Property to be less than Defensible Title, or (ii) with respect to the environmental condition of a Property, a condition with respect to any of the Properties that (A) is identified by any Site Assessment conducted by or on behalf of Buyer and (B) constitutes a violation of Applicable Environmental Law or a breach of the representation and warranty set forth in any of Section 4.15(a), Section 4.15(b), Section 4.15(c), or Section 4.15(d) with respect to such Property, on the Closing Date; provided, however, that “Defect” shall exclude the following:

(a) defects based solely on a lack of information in Seller’s files or references to a document if such document is not in Seller’s files;

(b) defects arising out of lack of corporate or other entity authorization, unless Buyer provides affirmative evidence that the action was not authorized and results in another Person’s superior claim of title to the relevant Property;

(c) defects in the chain of title consisting of the failure to recite marital status in a document or omissions of successions of heirship or estate proceedings, unless Buyer provides affirmative evidence that such failure or omission could reasonably be expected to result in another Person’s superior claim of title to the relevant Property;

(d) defects based on a gap in Seller’s chain of title in the county or parish records, unless such gap is affirmatively shown to exist in such records by an abstract of title or title opinion (which documents shall be included in any notice of Asserted Defect);

(e) defects that have been cured by applicable statutes of limitation or prescription;

(f) defects arising out of a lack of survey, unless a survey is expressly required by applicable Laws;

(g) defects or irregularities arising out of uncancelled mortgages, judgments, or liens, the inscriptions of which, on their face, have expired as a matter of law prior to the Effective Time, or prior unreleased oil and gas leases which, on their face, expired more than ten (10) years prior to the Effective Time and have not been maintained in force and effect by production or operations pursuant to the terms of such leases; and

(h) defects disclosed on any Schedule or Exhibit.

 

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Section 8.3 Permitted Matters and Encumbrances. Notwithstanding any other provision in this Agreement to the contrary, the following matters (“Permitted Encumbrances”) shall not constitute, and shall not be asserted as, a Defect:

(a) royalties, nonparticipating royalty interests, net profits interests, overriding royalties, production payments, reversionary interests, and other burdens on production, to the extent that they do not, individually or in the aggregate, (i) reduce Seller’s Net Revenue Interest below that shown for any Unit or Well on Exhibit B, (ii) increase Seller’s Working Interest above that shown for any Unit or Well on Exhibit B without a corresponding increase in the Net Revenue Interest, or (iii) otherwise reduce the number of Net Leasehold Acres covered by, or the Net Revenue Interest for, (A) any Lease not within the geographic boundaries of the UGR Unit, or (B) any Lease within the geographic boundaries of the UGR Unit, as to subsurface intervals underlying such Lease located above and below the Unitized Interval, in either case, below the number of Net Leasehold Acres or below the Net Revenue Interest, as applicable, shown for such Lease on Schedule 3.2;

(b) all Leases, Contracts, Surface Rights, division orders, and other contracts, agreements and instruments applicable to the Properties, to the extent that they do not, individually or in the aggregate: (i) reduce Seller’s Net Revenue Interest below that shown for any Unit or Well on Exhibit B; (ii) increase Seller’s Working Interest above that shown for any Unit or Well on Exhibit B without a corresponding increase in the Net Revenue Interest; or (iii) otherwise reduce the number of Net Leasehold Acres covered by, or below the Net Revenue Interest for, (A) any Lease not within the geographic boundaries of the UGR Unit, or (B) any Lease within the geographic boundaries of the UGR Unit, as to subsurface intervals underlying such Lease located above and below the Unitized Interval, in either case, below the number of Net Leasehold Acres or below the Net Revenue Interest, as applicable, shown for such Lease on Schedule 3.2; or (iv) otherwise materially detract from the value, or materially interfere with the use or ownership, of the Properties;

(c) subject to compliance with Section 7.5, Consents other than Required Consents applicable to the Properties;

(d) preferential rights to purchase, Consents, and similar restrictions with respect to which waivers or consents are obtained by Seller from the appropriate Persons prior to the Closing Date, or for which the appropriate time period for asserting the right has expired, or which need not be satisfied prior to a transfer;

(e) liens for current Taxes or assessments not yet delinquent or, if delinquent, being contested in good faith by appropriate actions;

(f) materialman’s, mechanic’s, repairman’s, employee’s, contractor’s, lessor’s, operator’s, and other similar liens or charges arising in the ordinary course of business for amounts not yet delinquent (including any amounts being withheld as provided by Law), or if delinquent, being contested in good faith by appropriate actions;

(g) Routine Governmental Approvals;

 

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(h) rights of reassignment arising upon final intention to abandon or release all or any part of the Properties;

(i) easements, rights-of-way, servitudes, permits, surface leases, and other rights in respect of surface operations, to the extent that they do not, individually or in the aggregate: (i) reduce Seller’s Net Revenue Interest below that shown for each Unit or Well on Exhibit B; (ii) increase Seller’s Working Interest above that shown for each Unit or Well on Exhibit B without a corresponding increase in Net Revenue Interest; (iii) otherwise reduce the number of Net Leasehold Acres covered by, or the Net Revenues Interest for, (A) any Lease not within the geographic boundaries of the UGR Unit, or (B) any Lease within the geographic boundaries of the UGR Unit, as to subsurface intervals underlying such Lease located above and below the Unitized Interval, in either case, below the number of Net Leasehold Acres or below the Net Revenue Interest, as applicable, shown for such Lease on Schedule 3.2; or (iv) otherwise materially detract from the value, or materially interfere with the use or ownership, of the Properties;

(j) calls on production under existing Contracts;

(k) all rights reserved to or vested in any Governmental Authority to control or regulate any of the Oil and Gas Properties in any manner, and all obligations and duties under all applicable Laws or under any franchise, grant or Permit issued by any Governmental Authority pursuant to applicable Laws;

(l) any encumbrance on or affecting the Properties which is expressly assumed, bonded, or paid by Buyer at or prior to the Closing or which is satisfied and discharged in full by Seller at or prior to the Closing;

(m) any matters shown on Schedule 4.6; and

(n) any liens, charges, encumbrances, defects, or irregularities (i) which affect a Property from which Hydrocarbons have been and are being produced (or to which production of Hydrocarbons is allocable) for the last ten (10) years and for which no claim related to title has been made in writing by any Person during such ten-year period, and which would be accepted by a reasonably prudent purchaser engaged in the business of owning and operating oil and gas properties; or (ii) which (A) do not, individually or in the aggregate, materially detract from the value, or materially interfere with the use or ownership, of the Properties subject thereto or affected thereby (as currently used or owned), (B) would be accepted by a reasonably prudent purchaser engaged in the business of owning and operating oil and gas properties, and (C) do not reduce Seller’s Net Revenue Interest below that shown for the affected Unit or Well on Exhibit B, or increase Seller’s Working Interest above that shown for each Unit or Well on Exhibit B without a corresponding increase in the Net Revenue Interest, or otherwise reduce the number of Net Leasehold Acres covered by, or the Net Revenue Interest for, any Lease not within the geographic boundaries of the UGR Unit, or any Lease within the geographic boundaries of the UGR Unit, as to subsurface intervals underlying such Lease located above and below the Unitized Interval, in either case, below the number of Net Leasehold Acres, or below the Net Revenue Interest, as applicable, shown for such Lease on Schedule 3.2.

 

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Section 8.4 Seller’s Response to Asserted Defects. In the event that Buyer notifies Seller of one or more Asserted Defects:

(a) Election Related to Title Asserted Defects. If the relevant Asserted Defect relates to the title to a Property, then no later than two (2) Business Days after Seller’s receipt of Buyer’s notice of such Asserted Defect, Seller shall provide to Buyer written notice concerning whether Seller elects (i) to exclude the Property affected by the Asserted Defect from the transactions contemplated herein, whereupon such Property shall become an Excluded Property for purposes of this Agreement (the “Exclusion Election”), or (ii) to continue to treat the affected Property as a Property to be conveyed to Buyer pursuant hereto and to follow the procedure relating to title curative set forth in the succeeding provisions of this Article VIII (the “Retention Election”). The failure of Seller to deliver to Buyer notice of Seller’s election within such two Business Day period shall constitute an election by Seller of the Retention Election. Seller shall not be entitled to make the Exclusion Election permitted under this Section 8.4(a) with respect to Asserted Defects relating to the environmental condition of a Property.

(b) With respect to all Asserted Defects relating to the environmental condition of a Property, and those Asserted Defects relating to title matters as to which Seller has made, or is deemed to have made, the Retention Election, Seller shall have the option and right, but not the obligation, to cure or remedy such Asserted Defects at Seller’s sole cost, risk, and expense. If Seller elects to cure or remedy such an Asserted Defect, Seller shall provide to Buyer prompt written notice of such fact and will attempt to cure or remedy such Asserted Defect before the Closing; provided, however, that to permit Seller additional time to cure or remedy any such Asserted Defect, Seller may elect, at any time prior to the Closing, to withhold from the Closing some or all of the Properties subject to such Asserted Defects (regardless of whether such Asserted Defects relate to the title to a Property or the environmental condition of a Property) and to postpone the Closing solely with respect to such Properties until the Final Settlement Date. The Purchase Price due at Closing shall be reduced by the Allocated Value of those Properties for which Closing is delayed. Notwithstanding any such election to postpone Closing, Seller shall still have no obligation to cure Asserted Defects. If Seller cures or remedies such an Asserted Defect to Buyer’s reasonable satisfaction: (i) prior to the Closing Date, Seller shall convey to Buyer the affected Property on the Closing Date with no reduction in the Base Purchase Price; or (ii) in the case of Properties withheld from the Closing under this Section 8.4(b), prior to the Final Settlement Date, Seller shall convey the affected Property to Buyer, and Buyer shall pay to Seller an amount equal to the Allocated Value of the affected Property, subject to adjustment as provided in this Agreement, on the Final Settlement Date. As to those Properties subject to Asserted Defects that Seller has elected to attempt to cure or remedy under this Section 8.4, if Seller is unable to cure or remedy such Asserted Defects by the Closing Date or the Final Settlement Date, as applicable, such Asserted Defects shall be resolved as provided in Sections 8.5 and 8.6.

Section 8.5 Resolution of Uncured Defects. With respect to all Asserted Defects relating to the environmental condition of a Property and those Asserted Defects related to title matters as to which Seller has made the Retention Election:

(a) Agree Upon Adjustment. Buyer and Seller shall, with respect to each Property affected by such an Asserted Defect, attempt to agree upon the existence of such Asserted Defect, the method of remedying or curing same, and the appropriate downward adjustment of the Base Purchase Price to account for such Asserted Defect.

 

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(b) Resolution of Dispute. In the event of a dispute concerning any matter listed in Section 8.5(a) that is not resolved prior to the Closing, either Buyer or Seller may initiate arbitration of such dispute pursuant to Section 17.16. In that event, the affected Property shall be withheld from the Closing, the Closing shall proceed with respect to those Properties not subject to such a dispute and not otherwise withheld from the Closing pursuant to Section 8.4(b) or Section 7.5 or excluded from the transactions contemplated herein as Excluded Properties under Section 8.4(a), and the Purchase Price paid at Closing shall be reduced by the Allocated Value of the affected Property. The failure of Seller to initiate arbitration under Section 17.16 with respect to a dispute regarding any of such matters prior to the Closing shall not constitute a waiver, as applicable, by Seller of its objection to the relevant Asserted Defect. Following the issuance of the arbitrator’s decision, the terms of Section 8.5(c)(ii) shall apply.

(c) Uncured Defects. If Seller elects not to cure or remedy an Asserted Defect subject to this Section 8.5, or if Seller attempts but is unable to cure or remedy such an Asserted Defect to Buyer’s reasonable satisfaction: (i) by the Closing Date, Seller shall convey to Buyer the affected Property on the Closing Date, and subject to the terms of Section 8.8, receive a permanent reduction in the Base Purchase Price equal to the downward adjustment for the relevant Asserted Defect determined in a manner consistent with Section 8.6 and agreed to by the Parties; or (ii) in the case of Properties withheld from the Closing under Section 8.4(b) or Section 8.5(b), by the Final Settlement Date, Seller shall convey the affected Property to Buyer, and Buyer shall pay to Seller, on the Final Settlement Date, an amount equal to the Allocated Value of the affected Property, less, to the extent permitted under Section 8.8, the downward adjustment for such Asserted Defect determined in a manner consistent with Section 8.6 and agreed to by the Parties or determined by the arbitrator in accordance with Section 8.5(b).

Section 8.6 Adjustment for Certain Uncured Defects. In the event that Buyer raises as an Asserted Defect one of the following types of Defects, and such Defect is not cured prior to the Closing (or prior to the Final Settlement Date with respect to any Property that Seller has elected to exclude from the Closing pursuant to Section 8.4(b)), then:

(a) NRI Variance/Proportionate Price Reductions. If the Asserted Defect is a discrepancy in Net Revenue Interest for an Oil and Gas Property located within the Unitized Interval (including a Well), or a Lease not within the geographic boundaries of the UGR Unit, or a Lease within the geographic boundaries of the UGR Unit as to subsurface intervals underlying such Lease located above the top, and below the base, of the Unitized Interval, the downward adjustment to the Base Purchase Price for such Asserted Defect shall be equal to the product determined by multiplying the Allocated Value for the affected Oil and Gas Property or Lease by a fraction, (i) the numerator of which is equal to the positive difference obtained by subtracting the actual Net Revenue Interest of Seller in the affected Oil and Gas Property or Lease from the Net Revenue Interest set forth for such Oil and Gas Property or Lease in Exhibit B or Schedule 3.2, as applicable, and (ii) the denominator of which is the Net Revenue Interest shown for such Oil and Gas Property or Lease on Exhibit B or Schedule 3.2, as applicable; provided, however, that if the Asserted Defect does not affect the relevant Oil and Gas Property throughout its entire life, the downward adjustment shall be reduced to take into account the applicable time period only.

 

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(b) Net Leasehold Acres. As to (i) Leases not within the geographic boundaries of the UGR Unit and (ii) Leases within the geographic boundaries of the UGR Unit, as to subsurface intervals underlying such Leases located above the top, and below the base, of the Unitized Interval, if the Asserted Defect is a discrepancy in Net Leasehold Acres, the downward adjustment shall equal the product determined by multiplying the total Allocated Value for the affected Lease by a fraction, (x) the numerator of which is the positive difference obtained by subtracting the actual number of Net Leasehold Acres owned by Seller in the affected Lease from the number of Net Leasehold Acres shown for the affected Lease on Schedule 3.2, and (y) the denominator of which is the number of Net Leasehold Acres shown on Schedule 3.2 for the affected Lease.

(c) Liens/Payoff Amount. If the Asserted Defect is a lien, claim, or encumbrance, other than a Permitted Encumbrance, which is undisputed and liquidated in amount, the downward adjustment shall equal the amount of the payment required to be paid to remove such Asserted Defect.

(d) Environmental Defects. If the Asserted Defect relates to environmental matters, the downward adjustment shall be the Lowest Cost Response to address the matter. As used herein, “Lowest Cost Response” means the response required or allowed under Applicable Environmental Laws that cures, remediates, removes, or remedies the applicable present condition alleged to constitute the Asserted Defect at the lowest cost (considered as a whole, taking into consideration any material negative impact such response may have on the operations of the relevant Property) sufficient to comply with Environmental Laws as compared to any other response that is required or allowed under Applicable Environmental Laws. Notwithstanding the foregoing, the Lowest Cost Response shall not include (and Seller shall have no liability for): (i) the costs of Buyer’s and/or its Affiliates’ employees, project manager(s), or attorneys; (ii) expenses for matters that are costs of doing business (e.g., those costs that would ordinarily be incurred in the day-to-day operation of the Properties), or in connection with Permit renewal/amendment activities, maintenance on active RCRA waste management units, and operation and oversight of active RCRA waste management units; (iii) overhead costs of Buyer and/or its Affiliates; (iv) costs and expenses that would not have been required under Applicable Environmental Laws as they exist at the Effective Time; (v) costs or expenses incurred in connection with remedial or corrective action that is designed to achieve standards that are more stringent than those required for similar facilities or that fail to reasonably take advantage of applicable risk reduction or risk assessment principles allowed under Applicable Environmental Laws; and/or (vi) any costs or expenses relating to the assessment, remediation, removal, abatement, transportation, and disposal of any asbestos, asbestos containing materials, or NORM.

(e) Other Asserted Defects. If the Asserted Defect represents a matter other than one described in Sections 8.6(a)-(d) above, then the downward adjustment shall be determined by taking into account the Allocated Value of the affected Property, the portion of the Property affected by the Asserted Defect, the legal effect of the Asserted Defect, the potential economic effect of the Asserted Defect over the life of the affected Property, the values placed upon the Asserted Defect by Buyer and Seller, and such other factors as are necessary to make a proper evaluation.

 

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(f) No Duplication. Any of the adjustments for Asserted Defects calculated pursuant to this Section 8.6 shall be calculated without duplication of any amounts.

(g) In no event shall the downward adjustment to the Base Purchase calculated under this Article VIII exceed the Allocated Value of the affected Property.

Section 8.7 Possible Upward Adjustments. Should Seller determine (or should Buyer, in the course of its due diligence reviews contemplated by Section 8.1 above, determine) that the ownership of the Properties by Seller entitles Seller to (a) a decimal share of the production from a Well greater than the decimal share shown for such Well under the column headed “Net Revenue Interest” on Exhibit B, (b) a decimal share of the production from (i) a Lease not within the geographic boundaries of the UGR Unit, or (ii) a Lease within the geographic boundaries of the UGR Unit, as to the subsurface internals underlying such Lease located above the top, and below the base, of the Unitized Interval, that, in either case, is greater than the decimal share shown for such Lease under the column headed “Net Revenue Interest” on Schedule 3.2, or (c) Net Leasehold Acres with respect to (i) a Lease not within the geographic boundaries of the UGR Unit or (ii) a Lease within the geographic boundaries of the UGR Unit, but limited to the subsurface intervals underlying such Lease located above the top, and below the base, of the Unitized Interval, in excess of the Net Leasehold Acres for such Lease as provided on Schedule 3.2 (in each case, an “Interest Addition”), then Seller shall be entitled to apply the Interest Addition Value applicable to each Interest Addition agreed upon by Seller and Buyer or determined as provided in Section 17.16 as an offset to any reductions in the Base Purchase Price related to uncured Asserted Defects that Buyer is entitled to receive under this Article VIII (each, an “Offset”); provided, however, that in no event shall any such Interest Addition result in an increase in the Base Purchase Price. If arbitration is initiated under Section 17.16 with respect to a disputed Interest Addition or its Interest Addition Value, the affected Property shall be conveyed to Buyer at the Closing, and the Interest Addition Value shall be calculated in good faith by Seller. Following the issuance of the arbitrator’s decision, any Offset awarded by the arbitrators shall be taken into account in the Final Settlement Statement pursuant to Section 13.3.

Section 8.8 Limitations on Adjustments. Notwithstanding anything herein to the contrary, (i) in no event shall there be any adjustments to the Base Purchase Price or other remedies provided by Seller for any individual Asserted Defect which does not exceed One Hundred Thousand Dollars ($100,000); and (ii) in no event shall there be any adjustments to the Base Purchase Price or other remedies provided by Seller for Asserted Defects unless the amount of all such Asserted Defects (net of Interest Additions) that exceed the threshold in clause (i) and as finally agreed upon by the Parties or determined by the arbitrator pursuant to Section 8.5, in the aggregate, exceeds a deductible in an amount equal to three percent (3%) of the Base Purchase Price (the “Aggregate Deductible”), after which point Buyer shall be entitled to adjustments to the Base Purchase Price or other remedies available under this Article VIII with respect to all such Asserted Defects only to the extent of the excess over such Aggregate Deductible, subject to clause (i) of this Section 8.8 and any of Seller’s elections provided hereunder. The provisions of this Section 8.8 shall not apply to Required Consents, which shall be handled or treated under Section 7.5. The Allocated Value of any Oil and Gas Property excluded from the Closing as an Excluded Property pursuant to Section 8.4(a) may not be used in meeting the Aggregate Deductible.

 

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Section 8.9 EXCLUSIVE REMEDY. EXCEPT FOR THE SPECIAL WARRANTY OF TITLE SET FORTH IN THE CONVEYANCE, IN THE CASE OF MATTERS RELATED TO TITLE, AND THE REMEDIES SET FORTH IN ARTICLE XIV, IN THE CASE OF A BREACH OF THE REPRESENTATION AND WARRANTY SET FORTH IN SECTION 4.15, THE ADJUSTMENTS SET FORTH IN THIS ARTICLE VIII SHALL, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, BE THE EXCLUSIVE RIGHT AND REMEDY OF BUYER WITH RESPECT TO (I) TITLE TO THE ASSETS, (II) ANY MATTER OR CIRCUMSTANCE RELATING TO APPLICABLE ENVIRONMENTAL LAWS, (III) ENVIRONMENTAL LIABILITIES, (IV) THE RELEASE OF MATERIALS INTO THE ENVIRONMENT, OR (V) PROTECTION OF THE ENVIRONMENT OR HEALTH. EXCEPT FOR (a) THE REMEDIES SET FORTH IN THIS ARTICLE VIII, (b) THE SPECIAL WARRANTY OF TITLE SET FORTH IN THE CONVEYANCE, IN THE CASE OF MATTERS RELATING TO TITLE, AND (c) THE REMEDIES SET FORTH IN ARTICLE XIV, IN THE CASE OF A BREACH OF THE REPRESENTATION AND WARRANTY SET FORTH IN SECTION 4.15, BUYER, ON BEHALF OF ITSELF AND ALL BUYER INDEMNIFIED PARTIES, RELEASES, REMISES AND FOREVER DISCHARGES THE SELLER INDEMNIFIED PARTIES FROM ANY AND ALL DAMAGES, SUITS, LEGAL OR ADMINISTRATIVE PROCEEDINGS, CLAIMS, DEMANDS, DAMAGES, LOSSES, COSTS, LIABILITIES, INTEREST OR CAUSES OF ACTION WHATSOEVER, IN LAW OR IN EQUITY, KNOWN OR UNKNOWN, WHICH BUYER OR ANY BUYER INDEMNIFIED PARTIES MIGHT NOW OR SUBSEQUENTLY MAY HAVE, BASED ON, RELATING TO OR ARISING OUT OF, (I) ANY LIEN, ENCUMBRANCE, OBLIGATION OR DEFECT AFFECTING TITLE, OR OTHER DEFICIENCY IN OR ENCUMBRANCE ON TITLE TO ANY PROPERTY OR (II) ANY MATTER OR CIRCUMSTANCE RELATING TO ENVIRONMENTAL LAWS, THE RELEASE OF MATERIALS INTO THE ENVIRONMENT OR THE PROTECTION OF THE ENVIRONMENT OR HEALTH, EVEN IF SUCH CLAIMS OR DAMAGES ARE CAUSED, IN WHOLE OR IN PART, BY THE NEGLIGENCE (WHETHER SOLE, JOINT OR CONCURRENT, ACTIVE OR PASSIVE, BUT EXCLUDING GROSS NEGLIGENCE, WILLFUL MISCONDUCT, AND VIOLATION OF CRIMINAL LAW), STRICT LIABILITY, OR OTHER LEGAL FAULT OF THE SELLER INDEMNIFIED PARTIES.

Article IX.

Conditions Precedent to Closing Obligations

Section 9.1 Conditions Precedent to the Obligations of Buyer. The obligations of Buyer to consummate the transactions contemplated by this Agreement are subject to each of the following conditions being met:

(a) Representations True and Correct. Each and every representation of Seller under this Agreement shall be true and accurate in all respects as of the date when made and as of the time of Closing (other than representations and warranties that refer to a specified date, which need only be true and correct on and as of such specified date) except for such breaches, if any, as would not have a Material Adverse Effect (provided, that to the extent such representation or warranty is qualified by its terms by materiality or the requirement of a Material Adverse Effect, such qualification in its terms shall be inapplicable for purposes of this Section 9.1(a), and the Material Adverse Effect qualification contained in this Section 9.1(a) shall apply in lieu thereof).

 

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(b) Compliance with Covenants and Agreements. Seller shall have performed and complied in all material respects with (or compliance therewith shall have been waived by Buyer) each and every covenant and agreement required by this Agreement to be performed or complied with by Seller prior to or at the Closing.

(c) HSR Act. If the HSR Act is applicable to the transactions contemplated herein, the necessary waiting period for filings under the HSR Act shall have expired, or the United States Department of Justice and the Federal Trade Commission shall have otherwise consented to the consummation of the transactions contemplated in this Agreement, so that the Closing may proceed without violation thereof.

(d) Litigation. No suit, action, or other proceedings (excluding any such matter initiated by Buyer, its lenders, the initial purchasers purchasing any of Buyer’s or its Affiliate’s securities in connection with an offering memorandum or other similar document or any of their respective Affiliates) shall, on the Closing Date, be pending or threatened before any court or Governmental Authority seeking to restrain, enjoin, prohibit, declare illegal, or obtain material damages or other material relief in connection with the consummation of the transactions contemplated by this Agreement; and no preliminary injunction, permanent injunction, or order of any state or federal court shall have been entered against Seller, Buyer, or any of their respective Affiliates that restrains, enjoins, prohibits, or declares illegal the transactions contemplated by this Agreement.

(e) Financing. Buyer shall have obtained financing on terms reasonably acceptable to Buyer in an amount sufficient to permit Buyer to consummate the transactions contemplated herein.

(f) Seller’s Closing Obligations. Seller shall have delivered to Buyer the items required in Section 10.2 contemporaneously with the delivery by Buyer to Seller of the items required in Section 10.3.

Section 9.2 Conditions Precedent to the Obligations of Seller. The obligations of Seller to consummate the transactions contemplated by this Agreement are subject to each of the following conditions being met:

(a) Representations True and Correct. Each and every representation of Buyer under this Agreement shall be true and accurate in all material respects as of the date when made and as of the time of Closing (other than representations and warranties that refer to a specified date, which need only be true and correct on and as of such specified date) except for such breaches, if any, as would not have a Material Adverse Effect (provided, that to the extent such representation or warranty is qualified by its terms by materiality or the requirement of a Material Adverse Effect, such qualification in its terms shall be inapplicable for purposes of this Section 9.2(a), and the Material Adverse Effect qualification contained in this Section 9.2(a) shall apply in lieu thereof).

(b) Compliance With Covenants and Agreements. Buyer shall have performed and complied in all material respects with (or compliance therewith shall have been waived by Seller) each and every covenant and agreement required by this Agreement to be performed or complied with by Buyer prior to or at the Closing.

 

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(c) HSR Act. If the HSR Act is applicable to the transactions contemplated herein, the necessary waiting period for filings under the HSR Act shall have expired, or the United States Department of Justice and the Federal Trade Commission shall have otherwise consented to the consummation of the transactions contemplated in this Agreement, so that the Closing may proceed without violation thereof.

(d) Litigation. No suit, action, or other proceedings (excluding any such matter initiated by Seller or any of its Affiliates) shall, on the date of Closing, be pending or threatened before any court or Governmental Authority seeking to restrain, enjoin, prohibit, declare illegal, or obtain material damages or other material relief in connection with the consummation of the transactions contemplated by this Agreement; and no preliminary injunction, permanent injunction, or order of any state or federal court shall have been entered against Seller, Buyer, or any of their respective Affiliates that restrains, enjoins, prohibits, or declares illegal the transactions contemplated by this Agreement.

(e) Buyer’s Closing Obligations. Buyer shall have delivered to Seller the items required under Section 10.3 contemporaneously with the delivery by Seller to Buyer of items required by Section 10.2.

Article X.

Closing

Section 10.1 Closing. The closing (herein called the “Closing”) of the transaction contemplated hereby shall take place in the offices of Seller, no later than August 1, 2014, at 10:00 a.m. Central Time, or at such other date and time as Buyer and Seller may mutually agree upon (such date and time being herein called the “Closing Date”).

Section 10.2 Seller’s Closing Obligations. At the Closing:

(a) Delivery of Conveyance. Upon receipt of payment of the amount provided in Section 10.3(a), Seller shall execute, acknowledge, and deliver to Buyer a conveyance of the Properties (the “Conveyance”), in the form attached hereto as Exhibit E (and together with Exhibits A, B, C, and D hereto, with such modifications as may be mutually agreed to by Buyer and Seller), effective as to runs of oil and deliveries of gas and for all other purposes (subject to the terms of this Agreement) as of 7:00 o’clock a.m., local time at the locations of the Properties, respectively, on April 1, 2014 (herein called the “Effective Time”), in sufficient numbers of counterparts to permit recording in all relevant jurisdictions.

(b) Letters in Lieu. Seller shall, if requested by Buyer, execute and deliver to Buyer letters in lieu of transfer orders (or similar documentation) prepared by Buyer, in form acceptable to both Parties.

(c) Change of Operator Forms. Subject to Section 7.6, Seller shall execute and deliver to the Buyer, on forms prepared by Buyer and acceptable to Seller, Railroad Commission of Texas Forms P-4 for each of the Wells operated by Seller and such other correspondence and notices as may be required under Section 7.6.

 

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(d) FIRPTA Certificate. Seller shall deliver to Buyer an executed statement described in Treasury Regulation §1.1445-2(b)(2) certifying that Seller is not a foreign Person within the meaning of the Code.

(e) Releases of Liens; Required Consents. Seller shall deliver to Buyer (i) releases of all liens and security interests for borrowed money (if any) encumbering the Properties that do not constitute Permitted Encumbrances and (ii) subject to Section 7.5(b), the Required Consents with respect to the Properties conveyed at Closing.

(f) Officer Certificate. Seller shall deliver to Buyer a certificate, dated and effective as of the Closing Date, and executed by the president or an authorized vice president of Seller, certifying to Buyer that, on the Closing Date, the representations and warranties of Seller contained in this Agreement are true and correct in all material respects (and in all respects, in the case of representations and warranties qualified by materiality or the requirement of a Material Adverse Effect) and that all covenants of Seller contained herein have been performed in all material respects.

(g) Transition Services Agreement. Seller shall execute and deliver the Transition Services Agreement in the form attached hereto as Exhibit F.

(h) Other Actions. Seller shall execute and deliver such other documents and take such other actions as are provided for elsewhere in this Agreement or as may be necessary to consummate the transactions contemplated herein.

Section 10.3 Buyer’s Closing Obligations. At the Closing:

(a) Payment to Seller. Buyer shall deliver to Seller, by wire transfer of immediately available U.S. funds to accounts designated by Seller in a bank located in the United States, an amount equal to the Purchase Price, as adjusted pursuant to Section 13.1 and reflected in the Initial Settlement Statement.

(b) Succession by Buyer. Buyer shall (i) furnish to Seller such evidence (including evidence of satisfaction of all applicable bonding requirements) as Seller may require to demonstrate that Buyer is qualified with the applicable Governmental Authorities to succeed Seller as the owner and, where applicable, operator of the Properties, (ii) with respect to Properties operated by Seller or third Person operators where Buyer is to succeed Seller or such third Person operator as operator of the relevant Property, execute and deliver to Seller appropriate evidence reflecting the change of operator as required under Section 7.6, and (iii) execute and deliver to Seller such other forms as Seller may reasonably request for filing with the applicable Governmental Authorities to reflect Buyer’s assumption of plugging and abandonment liabilities with respect to the Wells.

(c) Conveyance. Buyer shall execute, acknowledge, and deliver to Seller all counterparts of the Conveyance duly executed by Buyer.

(d) Letters in Lieu. Buyer shall execute and deliver to Seller executed counterparts of any letters in lieu delivered under Section 10.2(b).

 

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(e) Officer Certificate. Buyer shall deliver to Seller a certificate, dated and effective as of the Closing Date, executed by the president or an authorized vice president of Buyer, certifying to Seller that, on the Closing Date, the representations and warranties of Buyer contained in this Agreement are true and correct in all material respects (and in all respects, in the case of representations and warranties qualified by materiality or the requirement of a Material Adverse Effect) and that all covenants of Buyer contained herein have been performed in all material respects.

(f) Transition Services Agreement. Buyer shall execute and deliver the Transition Services Agreement in the form attached hereto as Exhibit F.

(g) Other Actions. Buyer shall execute and deliver such other documents and take such other actions as are provided for elsewhere in this Agreement or as may be necessary to consummate the transactions contemplated herein.

Article XI.

Termination.

Section 11.1 Termination. Subject to Section 11.2, this Agreement shall be terminated: (a) at any time prior to the Closing by the mutual prior written consent of Seller and Buyer; (b) by Seller if the Closing has not occurred on or before August 8, 2014 (the “Termination Date”); (c) by the Party not in material breach or material default of its obligations under this Agreement if, prior to the Closing Date, the other Party is in material breach or material default of its obligations under this Agreement; (d) by Buyer, if (i) the Closing does not occur because any condition set forth in Section 9.1 to be fulfilled or satisfied by Seller has not been fulfilled or satisfied by Seller or waived by Buyer at or prior to the Closing Date, and (ii) Buyer has fulfilled the condition set forth in Section 9.1(e) and is not the party against whom any pending matter described in Section 9.1(d) has been commenced or any injunction or order referred to in Section 9.1(d) has been entered; (e) by Seller, if (i) the Closing does not occur because any condition set forth in Section 9.2 to be fulfilled or satisfied by Buyer has not been fulfilled or satisfied by Buyer or waived by Seller, and (ii) Seller is not the party against whom any pending matter described in Section 9.2(d) has been commenced or any injunction or order referred to in Section 9.2(d) has been entered; (f) by Seller at its option, if Buyer has not fulfilled the condition set forth in Section 9.1(e) by July 25, 2014; (g) by Buyer, if Buyer has not fulfilled the condition set forth in Section 9.1(e) by the Closing Date; or (h) by Seller or Buyer, at each Party’s option, if the aggregate amount by which the Base Purchase Price is reduced under the terms of Article VIII and Section 7.5 (exclusive of the amounts required to discharge the indebtedness (if any) secured by the liens and security interests for which Seller is obligated to deliver releases at the Closing), as such reduction is calculated with respect to any item, at Seller’s option, pursuant to Section 8.6 or Buyer’s proposed downward adjustment for such item, equals or exceeds ten percent (10%) of the Base Purchase Price; provided, however, that if a Property has been excluded from the Closing pursuant to Section 8.4(a), the full Allocated Value of such Excluded Property shall be taken into account in determining whether the right to terminate under this clause (h) has been triggered, but with respect to Properties that have been withheld from the Closing pursuant to Section 8.4(b) or Section 8.5(b), only the amount of the reduction of the Base Purchase Price calculated for the relevant Asserted Defect, at Seller’s option, pursuant to Section 8.6 or Buyer’s proposed downward adjustment for such Asserted Defect, and not the full Allocated Value of the affected Property, shall be taken into account in

 

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determining whether the right to terminate under this clause (h) has been triggered. Termination under clauses (b), (c), (d), (e), (f), (g), or (h) shall not be effective until the Party electing to terminate has delivered written notice to the other Party of its election to so terminate. Notwithstanding the foregoing, if a Party fails to satisfy or fulfill the conditions precedent to the other Party’s obligation to close hereunder, or if such first Party is otherwise in material breach or material default of its obligations hereunder, such a breaching or defaulting Party shall not be entitled to exercise any right of termination under this Section 11.1.

Section 11.2 Effect of Termination. If this Agreement is terminated pursuant to Section 11.1, this Agreement shall become void and of no further force or effect (except for the provisions of this Section 11.2 and Sections 7.3, 14.5, 16.1, 17.3, 17.4, 17.6, 17.7, 17.8, 17.12, 17.15, 17.16, 17.17, and 17.18, and of the Confidentiality Agreement, which shall survive such termination and continue in full force and effect), and Seller shall be free immediately to enjoy all rights of ownership of the Properties and to sell, transfer, encumber, or otherwise dispose of the Properties to any Person without any restriction under this Agreement. Notwithstanding anything to the contrary in this Agreement, if this Agreement is terminated (a) by Seller and Buyer pursuant to Section 11.1(a), (b) by Seller pursuant to Section 11.1(b) (if Buyer is not in breach under this Agreement), (c) by Buyer pursuant to Section 11.1(d) if the conditions set forth in, respectively, Section 9.1(c) and Section 9.1(d) are not fulfilled, (d) by Seller pursuant to Section 11.1(e) if the conditions set forth in, respectively, Section 9.2(c) or Section 9.2(d) are not fulfilled, (e) by Buyer pursuant to Section 11.1(g), (f) by Seller pursuant to (i) Section 11.1(f) or (ii) Section 11.1(e) if Buyer fails to close because of Buyer’s failure to fulfill the condition set forth in Section 9.1(e), or (g) by Seller or Buyer pursuant to Section 11.1(h), then except as provided hereinafter, neither Party shall have any further liability to the other Party as the result of such termination; provided, however, that no such termination shall relieve any Party from liability to the other Party at law or in equity for any failure to perform or observe in any material respect any of its agreements or covenants contained herein which are to be performed or observed at or prior to the Closing. If (i) Buyer becomes authorized and seeks to terminate this Agreement pursuant to Section 11.1(c) or Section 11.1(d) for any reason other than the failure of the conditions set forth in, respectively, Section 9.1(c), Section 9.1(d), or Section 9.1(e) to be fulfilled or (ii) Seller becomes authorized and seeks to terminate this Agreement pursuant to Section 11.1(b) (if Buyer is in breach of this Agreement), Section 11.1(c), or Section 11.1(e) for any reason other than the failure of the conditions set forth in, respectively, Section 9.1(e), Section 9.2(c), or Section 9.2(d) to be fulfilled, then in addition to such right of termination, the Party entitled to terminate this Agreement shall be entitled to pursue any and all other remedies available to such Party at law or in equity, including the right to file suit to seek damages for breach of this Agreement (subject to the limits set forth in Section 17.4), but excluding the right to seek specific performance; provided, however, that if Buyer fulfills the condition set forth in Section 9.1(e), and Seller otherwise becomes authorized to terminate this Agreement pursuant to Section 11.1(b), Section 11.1(c), or Section 11.1(e), in each case for any reason other than the failure of the conditions set forth in, respectively, Section 9.1(c) or Section 9.2(c) to be fulfilled, then in lieu of termination, Seller shall have the option and right to enforce the remedy of specific performance in any court of the United States or any state thereof having jurisdiction. In this regard, the Parties agree that Seller would be irreparably harmed by the unexcused refusal of Buyer to consummate the Closing. Therefore, Seller shall be entitled to injunctive relief in connection with its right to enforce specific performance under this Section 11.2. To the extent that the remedy of specific performance is available to Seller under this Section 11.2, Buyer agrees not to raise any objections to Seller’s assertion of the equitable

 

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remedy of specific performance to specifically enforce the terms and provisions of this Agreement and compliance with the covenants and agreements of Buyer under this Agreement. Buyer further agrees that Seller’s right to specific performance shall not in any respect waive Seller’s right to any other form of relief that may be available to it under this Agreement in the event that the remedies provided for in this Section 11.2 are not available or otherwise are not granted. If a Party resorts to legal proceedings to enforce this Agreement or any part thereof, the prevailing Party in such proceedings shall be entitled to recover all costs incurred by such Party, including reasonable attorneys’ fees, in addition to any other relief to which such Party may be entitled.

Article XII.

Post-Closing Actions

Section 12.1 Transfer of Files. Subject to the terms of the Transition Services Agreement, Seller will deliver to Buyer, at Buyer’s expense, and within thirty (30) days after the Closing Date, all of the Records, other than those which Seller cannot provide to Buyer without, in its opinion, breaching, or risking a breach of, confidentiality agreements with other parties, or waiving, or risking waiving, legal privilege. Seller may, at its election, make and retain copies of any or all such files. Buyer shall preserve all files so delivered by Seller in accordance with its records retention policy, as same may be amended from time to time (or such longer period of time as Seller may request for those Records relevant for Tax audit purposes), or, if any of the Records pertain to a claim pending at the time when such Records would otherwise be destroyed, until such claim is finally resolved and the time for all appeals is exhausted. Buyer will allow Seller access (including the right to make copies at Seller’s expense) to such files at all reasonable times.

Section 12.2 Notifications by Buyer. Immediately after the Closing, Buyer shall be responsible for notifying all applicable operators, non-operators, oil and gas purchasers, and Governmental Authorities that it has purchased the Properties.

Section 12.3 Undisbursed Revenues. On the Closing Date, Seller shall disburse to Buyer, by means of a decrease in the Base Purchase Price pursuant to Section 13.1(b)(v), those monies (if any) relating to production of Hydrocarbons from the Properties prior to the Effective Time that Seller is obligated to pay or disburse to other Persons (including amounts held in suspense by Seller) and that, as of the Closing Date, have not been thus paid or disbursed, to the extent set out on Schedule 4.17. Subject to the terms of the Transition Services Agreement, Buyer shall take and apply such funds in a manner consistent with prudent oil and gas business practices to satisfy the claims of third Persons with respect to such monies, but limited only to the extent of the money actually paid or disbursed by Seller to Buyer. Seller shall cooperate with Buyer following the Closing to assure the proper disbursement of any such funds. Seller shall remain liable, and shall be solely responsible, for the disbursement of any and all funds owed to Persons (including amounts held in suspense by Seller) that are not paid or disbursed to Buyer.

Section 12.4 Confidentiality.

(a) If the Closing does not occur, and this Agreement is terminated in accordance with Article XI, the Confidentiality Agreement shall survive any such termination and shall remain in full force and effect between Seller and Buyer for the duration, and otherwise

 

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according to the terms, thereof. Upon the termination of this Agreement: (i) all data and information made available by Seller to Buyer or Buyer’s agents or representatives pursuant to the Confidentiality Agreement or this Agreement, and all data and information (including environmental information) discovered by Buyer pursuant to its due diligence activities hereunder, shall constitute and remain “Confidential Information” as defined in, and subject to the terms of, the Confidentiality Agreement; (ii) Buyer shall return to Seller all such data and information, and all photocopies thereof, in the possession of Buyer; and (iii) Buyer shall destroy all excerpts, studies, reports, analyses, work papers, and other documents prepared or used by Buyer or its representatives relating to or based upon such data and information.

(b) If the Closing occurs, Seller’s and Buyer’s respective obligations under the Confidentiality Agreement shall terminate as of the Closing Date. For a period of twelve (12) months after the Closing Date, except as provided hereinafter: (i) Seller and Buyer agree not to disclose, and to keep confidential, the Base Purchase Price and the Purchase Price; (ii) Seller agrees not to disclose, and to keep confidential, all data and all environmental information regarding the Leases, Units, and Wells obtained by Buyer during the course of its operational and environmental assessment of the Assets pursuant to Sections 7.1 and 7.2 (as to which, for purposes of this Section 12.4(b), Buyer shall be deemed to be the Disclosing Party and Seller shall be deemed to be the Recipient); and (iii) Buyer agrees not to disclose, and to keep confidential, all other information and data disclosed by Seller to Buyer prior to the Closing (other than the Records) and that Seller has designated in writing to Buyer as proprietary and confidential (as to which, for purposes of this Section 12.4(b), Seller shall be deemed to be the Disclosing Party and Buyer shall be deemed to be the Recipient). For purposes of this Agreement, the data and information to be kept confidential by, respectively, Seller and Buyer as provided in the preceding sentence shall be referred to as “Confidential Information.” With respect to Confidential Information, and for such twelve (12) month period after the Closing Date:

(i) Recipient shall not disclose, disseminate, or otherwise publish or communicate Confidential Information received hereunder to any third Person without the prior written consent of the Disclosing Party, except to the directors, members, managers, partners, officers, employees, and Affiliates of Recipient, as well as Recipient’s financial advisors, lenders, investment bankers, attorneys, auditors, engineers, potential accredited investors, and other consultants and representatives (collectively, “Representatives”) who have a “need to know” and who have been advised of the confidentiality obligations herein and have previously agreed to be bound by the terms hereof with regard to the Confidential Information. Recipient shall be responsible for the actions of its Representatives with respect to the Confidential Information. Recipient shall protect the Confidential Information received hereunder from disclosure to any third Person by using the same degree of care that it uses to prevent the unauthorized disclosure of its own confidential or proprietary information of like nature, but in no event less than a reasonable degree of care.

(ii) This Agreement imposes no obligations with respect to information that: (A) was in Recipient’s possession without a duty of confidentiality to the Disclosing Party before receipt from the Disclosing Party; (B) is or becomes a matter of public knowledge through no act or omission of Recipient; (C) is rightfully received by Recipient from a third Person without a duty of confidentiality; (D) is generalized

 

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know-how, ideas, concepts, processes, information, operations, techniques or development related to the Properties that are retained in intangible form by Seller, its members, managers or any of its employees, consultants or advisors, as the case may be, who have had access to the Confidential Information; or (E) is disclosed by Recipient with the Disclosing Party’s prior written approval or for reasons described in Section 12.4(b)(iii).

(iii) If Recipient is required to disclose Confidential Information by operation of Law (including as required under state or federal securities Laws or applicable stock exchange or quotation system requirements) or under compulsion of judicial process, no breach of this Section 12.4 shall occur by reason of such a disclosure; provided that, Recipient will disclose only such information as is legally required by applicable Law or order of a court of competent jurisdiction or other Governmental Authority, and will provide notice to the Disclosing Party so that the Disclosing Party may seek confidential treatment for any Confidential Information that is so disclosed.

Section 12.5 Financial Matters.

(a) Seller acknowledges that, until such time as the Properties have been included in the audited consolidated financial statement of Buyer or an Affiliate of Buyer for a complete fiscal year (such time, the “Outside Date”), Buyer or its Affiliates may be required to provide in (i) any offering memorandum or similar document relating to a private offering of securities of Buyer or an Affiliate of Buyer made pursuant to Rule 144A under the Securities Act of 1933, as amended (the “Securities Act”), or otherwise, and (ii) registration statements and reports filed by the Buyer or an Affiliate of Buyer under the Securities Act or the Securities Exchange Act of 1934, as amended, the following financial statements of Seller prepared in accordance with rules and regulations of the SEC, including Regulation S-X (including any restatements, corrections or revisions thereof, collectively, the “Seller Financial Statements”):

(i) audited financial statements of Seller as of and for the years ended December 31, 2012 and 2013; and

(ii) unaudited financial statements of Seller for the most recently completed interim period of 2014 preceding the Closing, as of the end of such period and for the comparable period of 2013.

From and after the date of this Agreement and until the first anniversary of the Closing Date, Seller shall (i) prepare, or cooperate with the Buyer and its Affiliates in preparing, and make available to Buyer and its Affiliates the Seller Financial Statements, (ii) cause Seller’s independent auditors to audit or review the Seller Financial Statements, as applicable, or cooperate in the audit or review of the Seller Financial Statements by Buyer’s or its Affiliates’ independent auditors, and deliver one or more customary representation letters from Seller to such auditors that are reasonably requested to allow such auditors to complete an audit or review of the Seller Financial Statements and to issue an opinion acceptable to such auditors with respect to such audit or review, (iii) cooperate with Buyer and its Affiliates in preparing any pro forma financial statements of Buyer or its Affiliates giving effect to the acquisition of the Properties by Buyer, (iv) provide to Buyer, its Affiliates and their independent auditors reasonable access to the books, records, information and documents that are related to the Seller

 

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Financial Statements, that are reasonably requested by Buyer or its Affiliates and that are in Seller’s possession or control but not in Buyer’s possession or control, and (v) provide to Buyer, its Affiliates and their independent auditors reasonable access to Seller’s officers who were responsible for preparing the Seller Financial Statements or maintaining the financial records and work papers and other supporting documents used in the preparation of the Seller Financial Statements. In addition, until the Outside Date, Seller shall use its commercially reasonable efforts to obtain the consent of the independent auditor of Seller that conducted any audit of the Seller Financial Statements to the use of such independent auditor’s report, and to be named as an expert or as having prepared such report, in any SEC filing or offering memorandum or similar document referred to above.

(b) All of the information, including the Seller Financial Statements, provided by Seller pursuant to this Section 12.5 is given without any representation or warranty, express or implied, and no member of the Seller Indemnified Parties shall have any liability or responsibility with respect thereto. Buyer, for itself and for each member of the Buyer Indemnified Parties, hereby releases, remises and forever discharges each member of the Seller Indemnified Parties from any and all suits, legal or administrative proceedings, and Losses whatsoever, in law or in equity, known or unknown, which any member of the Buyer Indemnified Parties might now or subsequently may have, based on, relating to or arising out of Seller’s obligations pursuant to this Section 12.5 (including any representation or warranty, express or implied, included in any customary representation letter delivered by Seller to any auditor of Buyer, its Affiliates or Seller). From and after Closing, Buyer shall indemnify, defend and hold harmless the Seller Indemnified Parties from and against any and all Losses arising out of or relating to Seller’s obligations pursuant to this Section 12.5, any information (including Seller Financial Statements) provided pursuant to this Section 12.5, or any reliance on or use of any such information (including Seller Financial Statements) by any Person, EVEN IF CAUSED IN WHOLE OR IN PART BY THE NEGLIGENCE (WHETHER SOLE, JOINT OR CONCURRENT), STRICT LIABILITY OR OTHER LEGAL FAULT OF ANY INDEMNIFIED PERSON.

(c) Buyer will reimburse Seller, after demand in writing therefor, for any reasonable out-of-pocket costs incurred by Seller in complying with the provisions of this Section 12.5, other than fees and expenses of Seller’s independent auditor incurred on or before June 6, 2014.

Section 12.6 Transition Services. Notwithstanding the change of operatorship with respect to the Properties operated by Seller that will take place as of the Closing Date as provided herein, Seller and Buyer will execute and deliver, or cause to be delivered, at the Closing, the Transition Services Agreement substantially in the form attached hereto as Exhibit F, pursuant to which Seller will continue to provide certain services to Buyer for the period of time after the Effective Time, and at the rate of compensation, specified therein.

Section 12.7 Tax Matters.

(a) Property-Related Taxes. Seller is responsible for all Property-Related Taxes assessed with respect to the Properties for all periods prior to the Effective Time. To the extent that any such Property-Related Taxes attributable to the period prior to the Effective Time have not been paid prior to the Closing Date, Seller shall remain responsible for paying the same

 

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in a timely manner as required by applicable Law and shall provide evidence of such payment to Buyer promptly after such payment is made, and no adjustment to the Base Purchase Price shall be made with respect thereto. Buyer shall be responsible for, and shall bear and pay, all Property-Related Taxes assessed with respect to the Properties for any period that begins at and after the Effective Time.

(b) Production Taxes. All Production Taxes attributable to the Properties for the period prior to the Effective Time shall be paid by Seller, and all Production Taxes relating to the Properties for the period at and after the Effective Time shall be paid by Buyer.

(c) Cooperation. Each of Seller and Buyer shall provide to the other Party reasonable information which may be required for the purpose of preparing Tax returns and responding to any audit by any taxing jurisdiction. Each of Seller and Buyer shall cooperate with all reasonable requests of the other Party made in connection with contesting the imposition of Taxes. Neither Seller nor Buyer shall be required at any time to disclose to the other any Tax returns or other confidential Tax information unrelated to the ownership or operation of the Properties.

Article XIII.

Accounting Adjustments

Section 13.1 Adjustments for Revenues and Expenses. Appropriate adjustments to the Base Purchase Price and the Purchase Price, as applicable, shall be made between Buyer and Seller as follows:

(a) The Base Purchase Price will be increased, without duplication, by: (i) the amount of all Property Costs and other costs (including drilling and completion costs for the Uncompleted Wells) incurred and paid by Seller in the operation of the Properties after the Effective Time; (ii) an aggregate Two Hundred Fifty Thousand Dollars ($250,000) per month for the period between the Effective Time and the Closing Date (prorated for any partial months as applicable), such amount representing the operator’s general and administrative costs and fixed overhead costs with respect to the Properties; (iii) any increase required as the result of Seller’s payment of any Taxes allocated to Buyer pursuant to the proration of Property-Related Taxes and Production Taxes under Section 12.7; (iv) the value of Hydrocarbons in storage as of the Effective Time, determined in accordance with Section 13.1(c)(i); and (v) any amounts determined pursuant to Section 13.5; and

(b) The Base Purchase Price will be decreased, without duplication, by: (i) the aggregate amount of the proceeds from the sale of all Hydrocarbons (net of (A) any royalties, overriding royalties, production payments, net profits interests, and other burdens on or payable out of production, (B) any gathering, processing, and transportation costs and any Production Taxes deducted, and not reimbursed to Seller, by the purchaser of production) produced from the Properties between the Effective Time and the Closing Date that are received and retained by Seller; (ii) an amount equal to the Allocated Value of those Oil and Gas Properties excluded from the Closing due to outstanding Required Consents as provided in Section 7.5; (iii) the aggregate amount of any Asserted Defects for which Buyer is entitled to an adjustment as determined in accordance with Article VIII; (iv) the Allocated Value of any Oil and Gas Properties excluded from the Closing in accordance with Section 8.4(b); (v) all amounts held in

 

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suspense by Seller subject to Section 12.3; (vi) any amount for Casualty Loss as determined in accordance with Section 15.1; and (vii) any reduction required as the result of Buyer’s payment of any Taxes allocated to Seller pursuant to the proration of Property-Related Taxes and Production Taxes under Section 12.7.

(c) It is agreed that, in making such adjustments:

(i) oil which was produced from the Oil and Gas Properties before the Effective Time and which was, on the Effective Time, stored in tanks above the pipeline connection at the Effective Time that is credited to Seller’s interest in the Wells in accordance with gauging and other customary industry procedures, will be valued based on the actual price paid or, if not yet sold, the price paid at the time sold, less Production Taxes and gravity adjustments deducted by the purchaser of such oil;

(ii) Property-Related Taxes, right-of-way fees, insurance premiums, and Property Costs (excluding delay rentals, lease bonuses, minimum royalties, option payments, lease extension payments, and shut-in royalties) that are paid periodically shall be prorated based on the number of days in the applicable period falling before, at, or after the Effective Time, except that Production Taxes shall be prorated based on the number of units actually produced, purchased, or sold, or the proceeds of sale, as applicable, before, at, or after the Effective Time; and

(iii) no consideration shall be given to the local, state, or federal income Tax liabilities of any Party.

(d) The adjustment described in Section 13.1(b)(i) shall serve to satisfy, up to the amount of the adjustment, Buyer’s entitlement under Section 2.1 to Hydrocarbon production from or attributable to the Properties during the period from the Effective Time to the Closing Date, and to the value of other income, proceeds, receipts and credits earned with respect to the Properties during such period, and Buyer shall not have any separate rights to receive any production or income, proceeds, receipts, or credits with respect to which an adjustment under Section 13.1(b)(i) has been made.

(e) Except to the extent accounted for in the adjustments to the Base Purchase Price made under Section 13.1(a) or (b): (i) Buyer shall be entitled to all Hydrocarbon production from or attributable to the Oil and Gas Properties at and after the Effective Time (and all products and proceeds attributable thereto), and to all other income, proceeds, receipts, and credits earned with respect to the Properties at or after the Effective Time, except that Seller shall retain all COPAS overhead charges for Properties operated by Seller to which it is entitled for the period between the Effective Time and the Closing Date; and (ii) Seller shall be entitled to all Hydrocarbon production from or attributable to the Oil and Gas Properties prior to the Effective Time (and all products and proceeds attributable thereto), and to all other income, proceeds, receipts, and credits earned with respect to the Properties prior to the Effective Time. “Earned” and “incurred”, as used in this Agreement, shall be interpreted in accordance with GAAP and Council of Petroleum Accountants Society (“COPAS”) standards.

Section 13.2 Initial Adjustment at Closing. At least five (5) days before the Closing Date, Seller shall provide to Buyer a statement (the “Initial Settlement Statement”) estimating

 

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the Purchase Price, giving effect to and showing its good faith computations of the amount of the adjustments provided for in Section 13.1 based on (A) amounts which, prior to such time, have actually been paid or received by Seller and (B) amounts calculated as provided in Section 7.5, Article VIII, and Section 13.5, if any. Buyer and Seller shall attempt to agree upon such adjustments prior to the Closing; provided that if such agreement is not reached, Seller’s computation of the Purchase Price shall be used at the Closing (except as to any adjustments for Asserted Defects which shall be resolved in accordance with Article VIII), subject to further adjustment under Section 13.3 after the Closing.

Section 13.3 Adjustment Post Closing. On or before 120 days after the Closing, Seller shall prepare a “Final Settlement Statement” and deliver same to Buyer, setting forth in reasonable detail the dollar amount, nature, and basis of each additional adjustment to the Base Purchase Price not reflected in the Initial Settlement Statement (whether the same be made to account for expenses or revenues not considered in making the adjustments made at the Closing, the resolution of Asserted Defects, the receipt of Required Consents, or to correct errors made in the adjustments made at the Closing). Buyer will assist Seller in the preparation of the Final Settlement Statement by providing Seller with any data or information reasonably requested by Seller. The Final Settlement Statement shall become final and binding on the Parties on the thirtieth (30th) day following receipt thereof by Buyer (the “Final Settlement Date”), unless Buyer gives written notice of its disagreement to Seller prior to such date. In order to be valid, any such notice shall specify in reasonable detail the dollar amount, nature, and basis of any disagreement so asserted. If Buyer and Seller are unable to agree on the Final Settlement Statement during such thirty-day period, Buyer and Seller shall submit all unresolved claims and amounts for arbitration in accordance with Section 17.16. If the amount of the Purchase Price as set forth on the Final Settlement Statement exceeds the amount of the Purchase Price paid at the Closing, then Buyer shall pay to Seller the amount by which the Purchase Price set forth on the Final Settlement Statement exceeds the amount of the Purchase Price paid at the Closing within five (5) Business Days after the Final Settlement Statement is agreed to or otherwise becomes final in accordance with this Section 13.3. If the amount of the Purchase Price as set forth on the Final Settlement Statement is less than the amount of the Purchase Price paid at the Closing, Seller shall pay to Buyer the amount by which the Purchase Price as set forth on the Final Settlement Statement is less than the amount of the Purchase Price paid at the Closing within five (5) Business Days after the Final Settlement Statement is agreed to or otherwise becomes final in accordance with this Section 13.3. During the period between the Closing and the point in time when the Final Settlement Statement has been agreed to or otherwise becomes final in accordance with this Section 13.3, (a) Buyer shall, on a monthly basis, pay over to Seller any revenue received by it with respect to the Properties which was, under Section 13.1, to be reserved by Seller, and such payments shall be reflected in the Final Settlement Statement; and (b) Seller shall, on a monthly basis, pay over to Buyer any revenue received by Seller with respect to the Properties which is, under Section 13.1, owed to Buyer, and such payments shall be reflected in the Final Settlement Statement. If a dispute regarding the Final Settlement Statement is resolved by arbitration, payment by the Party obligated to do so shall be due on the fifth (5th) Business Day after the arbitrator renders its decision.

Section 13.4 No Further Adjustments. Following the adjustments under Section 13.3, no further adjustments shall be made under this Article XIII, except as provided in Section 13.5 below.

 

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Section 13.5 Imbalance Adjustments. If, on the Closing Date, there exist imbalances in excess of the imbalances (if any) set forth on Schedule 4.13, Buyer or Seller shall give the other Party written notice of such fact prior to the Closing or within 120 days after the Closing. Thereafter, a determination shall be made (pursuant to Section 13.2 prior to the Closing, or Section 13.3 after the Closing) of (a) the amount, if any, by which the total actual amount of overproduction exceeds the total amount of overproduction as shown on Schedule 4.13, and (b) the amount, if any, by which the total actual amount of underproduction exceeds the total amount of underproduction shown on Schedule 4.13. The Base Purchase Price shall be decreased by an amount equal to the product of the actual total amount of overproduction (in Mcf) multiplied by the NYMEX closing price for natural gas on the Effective Time for deliveries of gas at the Henry Hub. The Base Purchase Price shall be increased by an amount equal to the product of the total actual amount of underproduction (in Mcf) multiplied by the NYMEX closing price for natural gas on the Effective Time for deliveries of gas at the Henry Hub. There shall be no adjustments for any imbalances discovered more than 120 days after the Closing, and the adjustments provided for in this Section 13.5 shall be Buyer’s sole and exclusive remedy for any overproduction, underproduction, or other imbalance related to the Properties.

Section 13.6 Gas Imbalances, Makeup Obligations. It is expressly understood and agreed that, upon the occurrence of Closing, but effective as of the Effective Time and subject to the adjustment in the preceding paragraph, Buyer shall succeed to and assume the position of Seller with respect to all gas imbalances and make-up obligations related to the Properties (regardless of whether such imbalances or make-up obligations arise at the wellhead, pipeline, gathering system, or other level, and regardless of whether the same arise under contract or otherwise). As a result of such succession, Buyer shall (a) be entitled to receive any and all benefits which Seller would have been entitled to receive by virtue of such position, and (b) be obligated to bear any detriments which Seller would have been obligated to bear by virtue of such position (including the rights to produce and receive or, the obligation to deliver to others, production volumes attributable to the Properties).

Article XIV.

Assumption and Indemnification

Section 14.1 Assumption and Indemnification By Buyer. If the Closing occurs, then from and after the Closing Date, Buyer shall (i) assume and agree to pay, perform, and discharge all obligations and liabilities, and (ii) indemnify, defend, and hold Seller, its Affiliates, and the officers, directors, managers, members, stockholders, general or limited partners, employees, agents, representatives, advisors, successors, and assigns of Seller or its Affiliates (the “Seller Indemnified Parties”) free and harmless from and against any and all claims, demands, actions, causes of action, liabilities, losses, damages, fines, penalties, costs, and expenses (including court costs and consultants’ and reasonable attorneys’ fees) of any kind or character (collectively, “Losses”) (each Loss, individually, a “Seller’s Indemnified Claim” and collectively, “Seller’s Indemnified Claims”), in each case, arising from or related to, directly or indirectly:

(a) any breach, asserted during the applicable survival period, of any warranty of Buyer made in this Agreement (provided that, for purposes of this Section 14.1, all qualifications relating to materiality or the requirement of a Material Adverse Effect contained in such representations and warranties shall be disregarded), or of any covenant or agreement of Buyer contained in this Agreement or any document executed in connection herewith,

 

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(b) except for liabilities for which Seller is required to indemnify Buyer pursuant to this Article XIV at the time a Claim Notice is delivered under Section 14.4, the ownership and/or operation of the Properties regardless of whether the same accrued or otherwise arose before, at, or after the Effective Time (including, without limitation, all liabilities and obligations arising under the Leases, Contracts, and agreements described in Section 2.1(d) above);

(c) except for liabilities for which Seller is required to indemnify Buyer pursuant to this Article XIV at the time a Claim Notice is delivered under Section 14.4, the condition of the Properties before, on, or after the Effective Time (including, without limitation, within such matters all obligations to properly plug and abandon, or replug and re-abandon, wells located on the Properties, to restore the surface and subsurface of the Properties, and to comply with, or to bring the Properties into compliance with, Applicable Environmental Laws, including conducting any remediation activities which may be required on or otherwise in connection with activities on the Properties), regardless of whether such condition or the events giving rise to such condition arose or occurred before, on or after the Effective Time; and

(d) all claims and liabilities relating to the payment of Taxes (including interest, penalties, and additions to Tax) for which Buyer has agreed to be responsible under the terms hereof.

THE FOREGOING ASSUMPTIONS AND INDEMNIFICATIONS OF BUYER SHALL APPLY WHETHER OR NOT SUCH DUTIES, OBLIGATIONS OR LIABILITIES, OR SUCH CLAIMS, ACTIONS, CAUSES OF ACTION, LIABILITIES, DAMAGES, LOSSES, COSTS OR EXPENSES ARISE OUT OF (i) NEGLIGENCE (INCLUDING SOLE NEGLIGENCE, SIMPLE NEGLIGENCE, CONCURRENT NEGLIGENCE, ACTIVE OR PASSIVE NEGLIGENCE, BUT EXPRESSLY NOT INCLUDING GROSS NEGLIGENCE OR WILLFUL MISCONDUCT) OF ANY SELLER INDEMNIFIED PARTIES, (ii) STRICT LIABILITY, OR (iii) ANY VIOLATION OF ANY LAW APPLICABLE TO THE OWNERSHIP OR OPERATION OF THE PROPERTIES, INCLUDING APPLICABLE ENVIRONMENTAL LAWS.

Section 14.2 Indemnification By Seller. If the Closing occurs, then from and after Closing, Seller shall retain liability for, and shall defend, indemnify, and hold Buyer, its Affiliates, and the officers, directors, managers, members, stockholders, general or limited partners, employees, agents, representatives, advisors, successors, and assigns of Buyer or its Affiliates (the “Buyer Indemnified Parties”) free and harmless from and against any and all claims, demands, actions, causes of action, liabilities, losses, damages, costs, and expenses (including court costs and consultants and reasonable attorneys’ fees) (individually, a “Buyer’s Indemnified Claim” and collectively, “Buyer’s Indemnified Claims”) arising from or related to, directly or indirectly:

(a) any breach, asserted during the applicable survival period, of any warranty (except for the representation and warranty in Section 4.13, as to which Buyer’s sole and exclusive remedy is found in Section 13.5) of Seller made in this Agreement (provided that, for purposes of this Section 14.2, all qualifications relating to materiality or the requirement of a Material Adverse Effect contained in such representations and warranties shall be disregarded), or of any covenant or agreement of Seller in this Agreement or any document executed in connection herewith;

 

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(b) arising out of third party claims for personal injury or death that relate in any way to the Properties, to the extent that the acts, omissions, events, or conditions giving rise to such claims occurred prior to the Closing Date;

(c) all royalties, overriding royalties, production payments, net profits interests, and other burdens on production from or allocable to the Leases, Units, and Wells attributable to the period of Seller’s ownership of the Properties prior to the Effective Time, to the extent attributable to production revenues actually received by Seller;

(d) all claims and liabilities related to the offsite disposal, during the period of Seller’s ownership of the Properties prior to the Closing Date, of Hazardous Substances used in connection with or otherwise related to the Properties;

(e) all claims (if any) of third Persons, whether as the result of audits or otherwise, to refunds and adjustments for payments made or received by Seller under the terms of the Leases or the Contracts and attributable to the period prior to the Effective Time;

(f) any Excluded Properties; and

(g) Property-Related Taxes and Production Taxes due and owing with respect to the Properties for all periods (and portions thereof) prior to the Effective Time.

THE FOREGOING ASSUMPTIONS AND INDEMNIFICATIONS OF SELLER SHALL APPLY WHETHER OR NOT SUCH DUTIES, OBLIGATIONS OR LIABILITIES, OR SUCH CLAIMS, ACTIONS, CAUSES OF ACTION, LIABILITIES, DAMAGES, LOSSES, COSTS OR EXPENSES ARISE OUT OF (i) NEGLIGENCE (INCLUDING SOLE NEGLIGENCE, SIMPLE NEGLIGENCE, CONCURRENT NEGLIGENCE, ACTIVE OR PASSIVE NEGLIGENCE, BUT EXPRESSLY NOT INCLUDING GROSS NEGLIGENCE OR WILLFUL MISCONDUCT) OF ANY BUYER INDEMNIFIED PARTIES, (ii) STRICT LIABILITY, OR (iii) ANY VIOLATION OF ANY LAW APPLICABLE TO THE OWNERSHIP OR OPERATION OF THE PROPERTIES, INCLUDING APPLICABLE ENVIRONMENTAL LAWS.

Section 14.3 Survival of Provisions/Limitations.

(a) The representations of Buyer and Seller contained in Article IV and Article VI of this Agreement shall survive for a period of nine (9) months after the Closing, except for the representations and warranties contained in Sections 4.1, 4.2, 4.3, 4.18, 4.19, 6.1, 6.2, 6.4, 6.7, 6.8, 6.9, 6.10, 6.11, and 6.12, which shall survive the Closing until the expiration of the applicable statute of limitations, and the representations and warranties contained in Section 4.5 and the first sentence of Section 4.7, which shall terminate at Closing. The covenants and other agreements of Seller and Buyer set forth in this Agreement that are to be performed at or prior to the Closing shall survive until the day following the Closing Date, and the covenants and other agreements of Seller and Buyer set forth in this Agreement that are to be performed following the Closing shall survive the Closing until fully performed. Representations, warranties, covenants, and agreements shall be of no further force and effect after the date of

 

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their expiration, after which time no claim with respect thereto may be made thereunder by any Party; provided that there shall be no termination of any bona fide claim asserted pursuant to this Agreement with respect to such a representation, warranty, covenant, or agreement prior to its expiration or termination date.

(b) The indemnities in Section 14.1(a) and Section 14.2(a) shall terminate as of the termination date of each respective representation, warranty, covenant, or agreement that is subject to indemnification, except in each case as to matters for which a specific written claim for indemnity has been delivered to the Indemnifying Party on or before such termination date. Buyer’s indemnities in Section 7.3, Section 12.5, Sections 14.1(b), (c), and (d) and Section 17.5, and Seller’s indemnities in Sections 14.2(f) and (g), shall, in each case, continue without time limit; provided that the foregoing shall not be deemed a waiver of any applicable statute of limitations. Seller’s indemnities in Section 14.2(b), (c), (d), and (e) shall survive the Closing for a period of two (2) years.

(c) Notwithstanding anything to the contrary contained in this Agreement, in no event shall Seller have any liability for any indemnification under Section 14.2 (excluding liability for any indemnification under Section 14.2(f) and (g)), (i) for any portion of an individual Loss that does not exceed Seventy-Five Thousand Dollars ($75,000), and then only to the extent such Loss exceeds Seventy-Five Thousand Dollars ($75,000), and (ii) for a portion of any Losses that exceed Seventy-Five Thousand Dollars ($75,000), until and unless the aggregate amount for all such Losses for which Claim Notices are timely delivered by Buyer exceed two percent (2%) of the Purchase Price, and then only to the extent such Losses exceed such amount.

(d) Notwithstanding anything to the contrary contained in this Agreement, in no event shall Seller’s aggregate liability to Buyer arising from or related to any breach of this Agreement, any representation, warranty, covenant or indemnity contained in this Agreement, exceed ten (10%) of the Base Purchase Price, except with respect to Section 14.2(f) and Section 14.2(g) in which case Seller’s aggregate liability shall not exceed the Purchase Price.

(e) Notwithstanding anything to the contrary contained in this Agreement, subject to rights of the Parties under Article XI, if the Closing occurs, this Article XIV contains the Parties’ sole and exclusive remedy against each other with respect to breaches of this Agreement, including breaches of the representations and warranties contained in Article IV and Article VI, and of the covenants and agreements that survive the Closing pursuant to the terms of this Agreement. Except for the remedies contained in this Article XIV, the rights of the Parties contained in Article XI, and the special warranty of title in the Conveyance, Buyer (on behalf of itself, each of the other Buyer Indemnified Parties and their respective insurers and successors in interest) releases, remises, and forever discharges the Seller Indemnified Parties from any and all suits, legal or administrative proceedings, claims, remedies, demands, damages, losses, costs, liabilities, interest, or causes of action whatsoever, in law or in equity, known or unknown, which such Parties might now or subsequently may have, based on, relating to or arising out of this Agreement, Seller’s ownership, use, or operation of the Properties, or the condition, quality, status or nature of the Properties, including, without limitation, rights to contribution under the Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended, and under other Environmental Laws, breaches of statutory or implied warranties, nuisance or other tort actions, rights to punitive damages, common law rights of contribution, rights under agreements between Seller and any Persons who are Affiliates of

 

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Seller, and rights under insurance maintained by Seller or any Person who is an Affiliate of Seller, EVEN IF CAUSED IN WHOLE OR IN PART BY THE NEGLIGENCE (WHETHER SOLE, JOINT OR CONCURRENT, BUT EXCLUDING GROSS NEGLIGENCE OR WILLFUL MISCONDUCT) OF ANY RELEASED PERSON, excluding, however, any existing contractual rights between (i) Buyer or any of Buyer’s Affiliates and (ii) Seller or any of Seller’s Affiliates under contracts between them relating to the Properties, other than this Agreement.

Section 14.4 Notice of Claim. To make a claim for indemnification under this Article XIV, a Seller Indemnified Party or a Buyer Indemnified Party, as applicable, seeking indemnification (the “Indemnitee”) shall notify the indemnifying party of its claim under this Article XIV, including the specific details of and specific basis under this Agreement for its claim (the “Claim Notice”). If indemnification pursuant to Section 14.1 or 14.2 is sought based on a claim or action by a third party (“Third Party Claim”), the Indemnitee shall provide its Claim Notice promptly after the Indemnitee has actual knowledge of the Third Party Claim, shall enclose a copy of all papers (if any) served with respect to the Third Party Claim, and shall allow the indemnifying party to assume and conduct the defense of the claim or action with counsel reasonably satisfactory to the Indemnitee, and shall cooperate with the indemnifying party in the defense thereof; provided, however, that the omission to give such notice to the indemnifying party shall not relieve the indemnifying party from any liability which it may have to the Indemnitee, except to the extent that the indemnifying party is prejudiced by the failure to give such notice and as otherwise provided in Section 14.3. The Indemnitee shall have the right to employ one separate counsel to represent the Indemnitee if the Indemnitee is advised by counsel that an actual conflict of interest makes it advisable for the Indemnitee to be represented by separate counsel, and the reasonable expenses and fees of such separate counsel shall be paid by the Indemnitee. If the indemnifying party does not admit its liability or admits its liability but fails to diligently defend or settle the Third Party Claim within twenty (20) days after its receipt of the Claim Notice, then the Indemnitee shall have the right to defend against the Third Party Claim at the sole cost and expense of the indemnifying party, with counsel of the Indemnitee’s choosing, subject to the right of the indemnifying party to admit its liability and assume the defense of the Third Party Claim at any time prior to settlement or final determination thereof. If the indemnifying party has not yet admitted its liability for a Third Party Claim, the Indemnitee shall send written notice to the indemnifying party of any proposed settlement and the indemnifying party shall have the option for ten (10) days following receipt of such notice to (i) admit in writing its liability for the Third Party Claim, and (ii) if liability is so admitted, reject, in its reasonable judgment, the proposed settlement. If indemnifying party fails to respond and admit in writing its liability during such ten (10) day period, the indemnifying party will be deemed not to have approved such proposed settlement, and any dispute regarding such liability shall be resolved pursuant to Section 17.8.

In the case of a claim for indemnification not based upon a Third Party Claim, the indemnifying party shall have thirty (30) days from its receipt of the Claim Notice to (i) cure the damages complained of, (ii) admit its liability for such damages, or (iii) dispute the claim for such damages or the amount of such damages. If the indemnifying party does not notify the Indemnitee, within such thirty-day period, that it has cured the damages or that it disputes the claim for such damages, the amount of such damages shall be deemed to have been disputed by the indemnifying party hereunder.

 

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Article XV.

Casualty Losses

Section 15.1 Casualty Loss. If, after the date of execution of this Agreement but prior to the Closing Date, any portion of the Properties is damaged, destroyed, or taken by condemnation or eminent domain, or otherwise suffers a reduction in value as a result of a casualty (a “Casualty Loss”), the Buyer will nevertheless be required to close, and the Purchase Price will be reduced by an amount equal to the lesser of (a) the Allocated Value of the Property affected by such Casualty Loss or (b) the amount of such Casualty Loss.

Article XVI.

Notices

Section 16.1 Notices. All notices and other communications required under this Agreement shall (unless otherwise specifically provided herein) be in writing and be delivered personally, by recognized commercial courier or delivery service which provides a receipt, by facsimile or e-mail (in either case with receipt acknowledged), or by registered or certified U.S. mail (postage prepaid with return receipt requested), at the following addresses:

 

If to Buyer:   Energy & Exploration Partners, LLC
  Two City Place
  100 Throckmorton Street, Suite 1700
  Fort Worth, Texas 76102
  Attention: Mr. Hunt Pettit
  Telephone No.: (817) 784-9766
  Facsimile No.: (817) 533-9840
  Email: hpettit@enxp.com
With a copy to:   Energy & Exploration Partners, LLC
  Two City Place
  100 Throckmorton Street, Suite 1700
  Fort Worth, Texas 76102
  Attention: Mr. Tom McNutt
  Telephone No.: (817) 494-7247
  Facsimile No.: (817) 533-9840
  Email: tmcnutt@enxp.com
If to Seller:   TreadStone Energy Partners, LLC
  16420 Park Ten Place
  Suite 100
  Houston, Texas 77084
  Attn: Key Sanford
  Telephone: 713-482-2994
  Facsimile: 281-492-1480
  E-Mail: key.sanford@TreadStone-ep.com

 

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With a copy to:   Kayne Anderson Capital Advisors
  811 Main Street, 14th Floor
  Houston, Texas, 77002
  Attn: Kevin Brophy
  Telephone: (713) 655-7559
  Facsimile: (713) 655-7355
  E-Mail: kbrophy@kaynecapital.com

or to such other place within the continental limits of the United States of America as a Party may designate for itself by giving notice to the other Party, in the manner provided in this Section 16.1, at least ten (10) days prior to the effective date of such change of address. All notices given by personal delivery or mail shall be effective on the date of actual receipt at the appropriate address. Notices given by facsimile or e-mail shall be effective upon actual receipt if received during recipient’s normal business hours or at the beginning of the next Business Day after receipt if received after recipient’s normal business hours.

Article XVII.

Miscellaneous Matters

Section 17.1 Change of Name. Unless otherwise authorized by Seller in writing, as promptly as practicable, but in any case within thirty (30) days after the Closing Date, Buyer shall eliminate the name “TreadStone Energy Partners, LLC” and any variants thereof from the Properties acquired pursuant to this Agreement and, except with respect to such grace period for eliminating existing usage, shall have no right to use any logos, trademarks, or trade names belonging to Seller or any of its Affiliates.

Section 17.2 Further Assurances. After the Closing, Seller and Buyer each agrees to take such further actions and to execute, acknowledge, and deliver all such further documents as are reasonably requested by the other Party for carrying out the purposes of this Agreement or of any document delivered pursuant to this Agreement.

Section 17.3 Waiver of Consumer Rights. It is the intention of the Parties that Buyer’s rights and remedies with respect to this transaction and with respect to all acts or practices of Seller, past, present, or future, in connection with this transaction shall be governed by legal principles other than the Texas Deceptive Trade Practices-Consumer Protection Act, Subchapter E of Chapter 17, Sections 17.41 et seq., of the Texas Business and Commerce Code, as amended (the “DTPA”). BUYER HEREBY WAIVES THE PROVISIONS OF THE TEXAS DECEPTIVE TRADE PRACTICES ACT, CHAPTER 17, SUBCHAPTER E, SECTIONS 17.41 THROUGH 17.63, INCLUSIVE (OTHER THAN SECTION 17.555, WHICH IS NOT WAIVED), TEX. BUS. & COM. CODE. IN ORDER TO EVIDENCE ITS ABILITY TO GRANT SUCH WAIVER, BUYER HEREBY REPRESENTS AND WARRANTS TO SELLER THAT BUYER (A) IS IN THE BUSINESS OF SEEKING OR ACQUIRING, BY PURCHASE OR LEASE, GOODS OR SERVICES FOR COMMERCIAL OR BUSINESS USE, (B) HAS KNOWLEDGE AND EXPERIENCE IN FINANCIAL AND BUSINESS MATTERS THAT ENABLE IT TO EVALUATE THE MERITS AND RISKS OF THE TRANSACTION CONTEMPLATED HEREBY, AND (C) IS NOT IN A SIGNIFICANTLY DISPARATE BARGAINING POSITION.

 

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Buyer expressly recognizes that the price for which Seller has agreed to perform its obligations under this Agreement has been predicated upon the inapplicability of the DTPA and this waiver of the DTPA. Buyer further recognizes that Seller, in determining to proceed with the entering into of this Agreement, has expressly relied on this waiver and the inapplicability of the DTPA.

Section 17.4 Expenses; No Special Damages. Each Party shall bear and pay all expenses (including, without limitation, legal fees) incurred by it in connection with the transaction contemplated by this Agreement. NOTWITHSTANDING ANYTHING HEREIN TO THE CONTRARY, NEITHER PARTY SHALL HAVE ANY OBLIGATION WITH RESPECT TO THIS AGREEMENT, OR OTHERWISE IN CONNECTION HEREWITH, FOR ANY SPECIAL, CONSEQUENTIAL, INDIRECT, OR PUNITIVE DAMAGES, INCLUDING LOST PROFITS OR LOSS OF REVENUE, EXCEPT TO THE EXTENT AN INDEMNITEE IS REQUIRED TO PAY PUNITIVE, SPECIAL, INDIRECT, OR CONSEQUENTIAL DAMAGES TO A THIRD PARTY THAT IS NOT AN INDEMNITEE.

Section 17.5 No Transfer Taxes. No Transfer Tax will be collected at the Closing from Buyer in connection with this transaction. If, however, this transaction is determined to be subject to sales or similar Transfer Taxes, for any reason, Buyer agrees to be solely responsible, and shall indemnify and hold the Seller Indemnified Parties harmless, for any and all Transfer Taxes (including related penalty, interest, or legal costs) due by virtue of this transaction on the Properties transferred pursuant hereto, and the Buyer shall remit such Transfer Taxes at that time. Seller and Buyer agree to cooperate with each other in demonstrating that the requirements for exemptions from such Transfer Taxes have been met. Notwithstanding the foregoing, Buyer shall bear all of the recording fees incurred and imposed upon, or with respect to, the transfer or other transactions contemplated hereby.

Section 17.6 Entire Agreement. This Agreement, together with all Exhibits, Schedules, and other documents to be delivered pursuant to the terms hereof, and the Confidentiality Agreement, contain the entire understanding of the Parties hereto with respect to the subject matter hereof and supersedes all prior agreements, understandings, negotiations, and discussions among the Parties with respect to such subject matter. In the event of a conflict between the terms and provisions of this Agreement and those of the Conveyance, the terms and provisions of this Agreement shall govern and control.

Section 17.7 Amendments, Waivers. This Agreement may be amended, modified, supplemented, restated, or discharged only by an instrument in writing executed by both Parties. Any failure by any Party or Parties to comply with any of its or their obligations, agreements or conditions herein contained may be waived in writing, but not in any other manner, by the Party or parties to whom such compliance is owed. No waiver of, or consent to a change in, any of the provisions of this Agreement shall be deemed or shall constitute a waiver of, or consent to a change in, other provisions hereof (whether or not similar), nor shall such waiver constitute a continuing waiver unless otherwise expressly provided.

Section 17.8 Choice of Law, etc. Without regard to principles of conflicts of Law that would direct the application of the Law of another jurisdiction, this Agreement shall be construed and enforced in accordance with and governed by the Laws of the State of Texas

 

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applicable to contracts made and to be performed entirely within such state and the Laws of the United States of America. EACH PARTY HERETO WAIVES, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY RIGHT IT MAY HAVE TO A TRIAL BY JURY IN RESPECT OF ANY ACTION, SUIT, OR PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT. Each Party hereto consents to personal jurisdiction in any action brought in the United States federal courts located within Harris County, Texas (or, if jurisdiction is not available in the United States federal courts, to personal jurisdiction in any action brought in the state courts located in Harris County, Texas) with respect to any dispute, claim, or controversy arising out of, in relation to, or in connection with this Agreement, and each of the Parties hereto agrees that any action instituted by it against the other with respect to any such dispute, controversy, or claim will be instituted exclusively in the United States District Court for the Southern District of Texas (or, if jurisdiction is not available in the United States District Court for the Southern District of Texas, then exclusively in the state courts located in Harris County, Texas). The Parties hereto hereby waive trial by jury in any action, proceeding, or counterclaim brought by any Party hereto against another in any matter whatsoever arising out of, in relation to, or in connection with this Agreement.

Section 17.9 Time of Essence. Time is of the essence in this Agreement and the performance of the obligations hereunder.

Section 17.10 No Assignment. Neither Party shall have the right to assign this Agreement, including any indemnification rights or any obligations or benefits hereunder (except to an Affiliate of the assigning Party by assignment, transfer of equity, merger, reorganization, or consolidation, provided that the Affiliate assumes all of the obligations of the assigning Party pursuant to this Agreement, and the assigning Party remains jointly and severally liable) without the prior written consent of the other Party first having been obtained, and any transfer in absence of such Consent shall be null and void.

Section 17.11 Successors and Assigns. Subject to the limitation on assignment contained in Section 17.10 above, this Agreement shall be binding on and inure to the benefit of the Parties hereto and their respective successors and assigns.

Section 17.12 No Press Releases. Neither Party shall make any public announcement with respect to the transaction contemplated hereby without the consent of the other Party (which consent shall not be unreasonably withheld, conditioned, or delayed). Despite the previous sentence, each Party has the right to disclose any information required by applicable Law, including the rules and regulations promulgated by the applicable securities regulators and stock exchanges.

Section 17.13 Counterpart Execution. For execution, this Agreement may be executed in counterparts, all of which are identical and all of which constitute one and the same instrument. It shall not be necessary for Buyer and Seller to sign the same counterpart. This instrument may be validly executed and delivered by facsimile or other electronic transmission.

Section 17.14 Replacement Bonds, Letters of Credit, and Guaranties. The Parties understand that none of the bonds, letters of credit and guarantees, if any, posted by Seller with Governmental Authorities and relating to the Properties are to be transferred to Buyer. On or before the Closing, Buyer shall obtain, or cause to be obtained, in the name of Buyer,

 

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replacements for such bonds, letters of credit, and guarantees as necessary to permit the cancellation of the bonds, letters of credit, and guarantees posted by Seller or to consummate the transactions contemplated by this Agreement. Buyer may also provide evidence that such replacements are not necessary as a result of existing bonds, letters of credit, or guarantees that Buyer has previously posted, as long as such existing bonds, letters of credit, or guarantees are adequate to secure the release of those posted by Seller.

Section 17.15 No Third Party Beneficiaries. Nothing in this Agreement shall entitle any Person other than Buyer and Seller to any claims, cause of action, remedy, or right of any kind, except the rights expressly provided to the Persons described in Sections 14.1 and 14.2.

Section 17.16 Arbitration.

(a) Any disagreement, difference, or dispute among the Parties provided in Section 8.5(b), Section 8.7, and Section 13.3 to be resolved by arbitration shall be resolved pursuant to arbitration according to the procedures set forth in this Section 17.16. Either Party may commence an arbitration proceeding hereunder by giving written notice to the other Party.

(b) If the dispute arises under Section 13.3, Seller and Buyer, no later than five (5) Business Days after the delivery of the notice commencing the arbitration proceeding, shall submit the dispute for resolution by the Designated Accountants. The Parties will present their positions to the Designated Accountants in the offices of the Designated Accountants in Houston, Harris County, Texas, within fifteen (15) days after the submission of the dispute unless otherwise required by the Designated Accountants. The Designated Accountants will be required to resolve the dispute in a fair and equitable manner in accordance with GAAP consistently applied within thirty (30) days after the presentation by the Parties of their positions.

(c) If the dispute arises under Section 8.5(b) or Section 8.7, Seller and Buyer, no later than five (5) Business Days after the delivery of the notice commencing the arbitration proceeding, shall each select an arbitrator. Promptly following their selection, the arbitrators selected by Seller and Buyer jointly shall select a third arbitrator. The arbitration shall be heard before, and decided by, the third arbitrator. All arbitrators selected under this Section 17.16(c) shall have at least eight (8) years of professional experience as either an oil and gas title examiner or an environmental consultant in the oil and gas industry, as applicable, shall not previously have been employed by either Party, and shall not have a direct or indirect interest in either Party or the subject matter of the arbitration. The arbitration hearing shall commence as soon as is practical, but in no event later than thirty (30) days after the selection of the third arbitrator. If any arbitrator selected under this Section 17.16(c) should die, resign, or otherwise be unable to perform his duties hereunder, a successor arbitrator shall be selected pursuant to the procedures set forth in this Section 17.16(c). The third arbitrator shall settle all disputes in accordance with the Commercial Arbitration Rules of the American Arbitration Association, to the extent that such Rules do not conflict with the terms of this Agreement. Any arbitration hearing shall be held in Houston, Harris County, Texas.

(d) The decisions of the Designated Accountants and the third arbitrator shall be final and binding on the Parties and, if necessary, may be enforced in any court of competent jurisdiction. The Law governing all disputes arising under this Section 17.16 shall be the Laws of the State of Texas and applicable federal Laws, but, in each case, without regard to conflicts

 

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of laws principles. The fees and expenses of the Designated Accountants and the arbitrators shall be shared one-half by Seller and one-half by Buyer. Any payment to be made as the result of any dispute resolved by arbitration hereunder shall be due on the later of (i) the date on which payments are due in connection with the Final Settlement Statement as provided in Section 13.3, or (ii) the fifth (5th) Business Day after the decision of the Designated Accountants or the arbitrator is rendered.

Section 17.17 References, Titles, and Construction.

(a) All references in this Agreement to exhibits, schedules, articles, sections, subsections and other subdivisions refer to corresponding exhibits, schedules, articles, sections, subsections and other subdivisions of this Agreement unless expressly provided otherwise.

(b) Titles appearing at the beginning of any of such subdivisions are for convenience only and shall not constitute part of such subdivisions and shall be disregarded in construing the language contained in such subdivisions.

(c) The words “this Agreement”, “this instrument”, “herein”, “hereof”, “hereby”, “hereunder” and words of similar import refer to this Agreement as a whole and not to any particular subdivision unless expressly so limited.

(d) Words in the singular form shall be construed to include the plural and vice versa, unless the context otherwise requires. Pronouns in masculine, feminine, and neuter genders shall be construed to include any other gender.

(e) Examples shall not be construed to limit, expressly or by implication, the matter they illustrate.

(f) The word “or” is not intended to be exclusive, and the word “include” and its derivatives means “includes, but is not limited to” and corresponding derivative expressions.

(g) All references herein to “$” or “dollars” shall refer to U.S. Dollars.

(h) The Exhibits listed in the List of Exhibits are attached hereto. Each such Exhibit is incorporated herein by reference for all purposes, and references to this Agreement shall also include such Exhibit, unless the context in which used shall otherwise require.

(i) Seller and Buyer have had the opportunity to exercise business discretion in relation to the negotiation of the details of the transaction contemplated hereby. This Agreement is the result of arm’s-length negotiations from equal bargaining positions. It is expressly agreed that this Agreement shall not be construed against any Party, and no consideration shall be given or presumption made, on the basis of who drafted this Agreement or any particular provision thereof.

Section 17.18 Severability. The provisions of this Agreement will be deemed severable and the invalidity or unenforceability of any provision will not affect the validity or enforceability of the other provisions hereof.

[Signature Pages to Follow]

 

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IN WITNESS WHEREOF, this Agreement is executed by Seller on the date set forth above.

 

SELLER
TreadStone Energy Partners, LLC
By:   /s/ Frank McCorkle
  Name:   Frank McCorkle
  Title:   President & CEO

 

[Signature Page to Purchase and Sale Agreement]


IN WITNESS WHEREOF, this Agreement is executed by Buyer hereto on the date set forth above.

 

BUYER
Energy & Exploration Partners, LLC
By:   /s/ Hunt Pettit
  Name:   Hunt Pettit
  Title:   Chief Executive Officer and President

 

[Signature Page to Purchase and Sale Agreement]



Exhibit 3.7

CERTIFICATE OF AMENDMENT

TO

CERTIFICATE OF DESIGNATIONS

OF

SERIES A MANDATORILY CONVERTIBLE PREFERRED STOCK

OF ENERGY & EXPLORATION PARTNERS, INC.

Energy & Exploration Partners, Inc., a Delaware corporation (the “Corporation”), through the undersigned duly authorized officer and in accordance with the provisions of Section 103 and 151 of the General Corporation Law of the State of Delaware, DOES HEREBY CERTIFY as of July 22, 2014 that pursuant to authority expressly conferred upon the Board of Directors of the Corporation (the “Board of Directors”) by the provisions of Section 151 of the General Corporation Law of the State of Delaware and Article IV of the Certificate of Incorporation of the Corporation (“Certificate of Incorporation”), and in accordance with the terms of the Certificate of Designations establishing the Corporation’s Series A Mandatorily Convertible Preferred Stock, as amended through the date hereof (the “Certificate of Designations”), the Board of Directors adopted by unanimous written consent in lieu of a meeting the following resolution on July 10, 2014 amending the Certificate of Designations:

RESOLVED, that pursuant to the authority vested in the Board of Directors by the provisions of Article IV of the Certificate of Incorporation and applicable law the Certificate of Designations be and hereby is amended as follows:

 

  1) The following definitions provided in SECTION 2 are hereby added or amended and restated as follows:

Apollo” shall mean, collectively, Apollo Investment Corporation, Apollo Special Opportunities Managed Account, L.P., Apollo Centre Street Partnership, L.P. and ANS U.S. Holdings Ltd.

Convertible Notes” shall mean $375 million principal amount of the Company’s 8.0% Convertible Subordinated Notes due 2019 to be issued on or about July 22, 2014 pursuant to an Indenture dated as of July 22, 2014 between the Company and U.S. Bank National Association, as trustee.

Convertible Notes Offering” shall mean the initial offering of the Convertible Notes to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act as described in the Offering Memorandum related to the Convertible Notes dated July 10, 2014.

Fully Diluted Outstanding” shall mean, when used with reference to Shares, at any date when the number of Shares is to be determined, all Shares outstanding at such date and all Shares issuable upon the exercise, conversion or exchange of any options, warrants or other securities that are directly or indirectly convertible into, or exercisable or exchangeable for, any Shares outstanding at such date other than the Convertible Notes.


Mandatory Conversion Date” shall mean, with respect to each Share of Preferred Stock held by any Holder, the date of the consummation of a Qualified Public Offering.

Note Purchase Agreement” shall mean the Note Purchase Agreement, dated as of April 8, 2013, by and among the Company as Issuer, Cortland Capital Market Services LLC, as administrative agent for the Holders and the Holders named therein, as amended, supplemented or otherwise modified prior to the date hereof.

Qualified Public Offering” shall mean the first public offering of the Common Stock (a) in which the aggregate gross proceeds to the Company and the stockholders selling such Common Stock, if any, equal or exceed $400.0 million and (b) following which, such Common Stock is listed on a U.S. national securities exchange. For the avoidance of doubt, if a Qualified Public Offering does not successfully close, it shall not prevent a future public offering from qualifying and being treated as a “Qualified Public Offering”.”

 

  2) The following definitions provided in SECTION 2 are hereby deleted in their entirety:

““Permitted Selling Stockholder” shall mean each Person who may elect to include Shares of Registrable Common Stock in a registration statement for a Qualified Initial Public Offering pursuant to the terms of the Registration Rights Agreement, to the extent of the number of Shares of Registrable Common Stock that such Person is entitled to include in any such registration statement pursuant to the Registration Rights Agreement.

Registrable Common Stock” shall have the meaning ascribed to such term in the Registration Rights Agreement.

Registration Rights Agreement” shall mean the Amended and Restated Registration Rights Agreement dated as of April 8, 2013 among the Company and the other parties thereto, as the same shall be amended from time to time.”

 

  3) SECTION 4(b)(i) is hereby amended and restated as follows:

“(i) create, authorize, issue or obligate the Company to issue any class of Shares or other equity security of the Company or options to purchase Shares or other equity security of the Company, other than (x) the issuance of Shares or options to purchase Shares to any officer, director, employee or consultant of the Company or any of its subsidiaries permitted under clause (ii) of this Section 4(b) and (y) the issuance of the Convertible Notes;”

 

-2-


  4) SECTION 4(b)(vi) is hereby amended and restated as follows:

“(vi) so long as (y) Significant Holders hold Warrants or Shares representing at least 20% of the Fully Diluted Outstanding Shares of the Company and (z) Highbridge, Apollo and their respective Affiliates collectively purchase at least $50 million principal amount of Convertible Notes in the Convertible Notes Offering and continue to hold at least $50 million principal amount of Convertible Notes, except as otherwise set forth in the Company’s approved annual budget, make any capital expenditure or acquisition of any assets or interest or other investment in any Person (whether by purchase of assets, purchase of stock, merger or otherwise) for a purchase price of $75 million or more in aggregate per calendar year;”

 

  5) SECTION 4(b)(vii) is hereby amended and restated as follows:

“(vii) so long as (y) Significant Holders hold Warrants or Shares representing at least 20% of the Fully Diluted Outstanding Shares of the Company and (z) Highbridge, Apollo and their respective Affiliates collectively purchase at least $50 million principal amount of Convertible Notes in the Convertible Notes Offering and continue to hold at least $50 million principal amount of Convertible Notes, approve the Company’s budget or any overages of either the total capital expenditures or the total general and administrative expenses greater than ten percent (10%) for any 12 month period from the date of the approved budget (it being acknowledged that Significant Holders holding a Significant Holder Majority have consented to the Company’s budget through July 31, 2015);”

 

  6) SECTION 4(b)(viii) is hereby amended and restated as follows:

“(viii) initiate any public offering of the Company or any subsidiary other than a Qualified Public Offering;”

 

-3-


IN WITNESS WHEREOF, the Corporation has caused this Certificate of Amendment to Certificate of Designations to be signed by its duly authorized officer as of the date first written above.

 

ENERGY & EXPLORATION PARTNERS, INC.
  By:  

/s/ Brian C. Nelson

    Brian C. Nelson
    Executive Vice President and Chief
Financial Officer

Certificate of Amendment to Certificate of Designations of Series A



Exhibit 3.8

CERTIFICATE OF AMENDMENT

TO

CERTIFICATE OF DESIGNATIONS

OF

SERIES B MANDATORILY CONVERTIBLE PREFERRED STOCK

OF ENERGY & EXPLORATION PARTNERS, INC.

Energy & Exploration Partners, Inc., a Delaware corporation (the “Corporation”), through the undersigned duly authorized officer and in accordance with the provisions of Section 103 and 151 of the General Corporation Law of the State of Delaware, DOES HEREBY CERTIFY as of July 22, 2014 that pursuant to authority expressly conferred upon the Board of Directors of the Corporation (the “Board of Directors”) by the provisions of Section 151 of the General Corporation Law of the State of Delaware and Article IV of the Certificate of Incorporation of the Corporation (“Certificate of Incorporation”), and in accordance with the terms of the Certificate of Designations establishing the Corporation’s Series B Mandatorily Convertible Preferred Stock, as amended through the date hereof (the “Certificate of Designations”), the Board of Directors adopted by unanimous written consent in lieu of a meeting the following resolution on July 10, 2014 amending the Certificate of Designations:

RESOLVED, that pursuant to the authority vested in the Board of Directors by the provisions of Article IV of the Certificate of Incorporation and applicable law the Certificate of Designations be and hereby is amended as follows:

 

  1) The following definitions provided in SECTION 2 are hereby added or amended and restated as follows:

Mandatory Conversion Date” shall mean, with respect to each Share of Preferred Stock held by any Holder, the date of the consummation of a Qualified Public Offering.

Qualified Public Offering” shall mean the first public offering of the Common Stock (a) in which the aggregate gross proceeds to the Company and the stockholders selling such Common Stock, if any, equal or exceed $400.0 million and (b) following which, such Common Stock is listed on a U.S. national securities exchange. For the avoidance of doubt, if a Qualified Public Offering does not successfully close, it shall not prevent a future public offering from qualifying and being treated as a “Qualified Public Offering”.”

 

  2) The following definitions provided in SECTION 2 are hereby deleted in their entirety:

““Permitted Selling Stockholder” shall mean each Person who may elect to include Shares of Registrable Common Stock in a registration statement for a Qualified Initial Public Offering pursuant to the terms of the Registration Rights Agreement, to the extent of the number of Shares of Registrable Common Stock that such Person is entitled to include in any such registration statement pursuant to the Registration Rights Agreement.


Registrable Common Stock” shall have the meaning ascribed to such term in the Registration Rights Agreement.

Registration Rights Agreement” shall mean the Amended and Restated Registration Rights Agreement dated as of April 8, 2013 among the Company and the other parties thereto, as the same shall be amended from time to time.”

 

-2-


IN WITNESS WHEREOF, the Corporation has caused this Certificate of Amendment to Certificate of Designations to be signed by its duly authorized officer as of the date first written above.

 

ENERGY & EXPLORATION PARTNERS, INC.

  By:  

/s/ Brian C. Nelson

    Brian C. Nelson
   

Executive Vice President and Chief

Financial Officer

Certificate of Amendment to Certificate of Designations of Series B



Exhibit 4.1

Execution Copy

 

 

ENERGY & EXPLORATION PARTNERS, INC.

8.00% CONVERTIBLE SUBORDINATED NOTES DUE 2019

 

 

INDENTURE

DATED AS OF JULY 22, 2014

 

 

U.S. BANK NATIONAL ASSOCIATION

AS TRUSTEE

 

 

 

 


TABLE OF CONTENTS

 

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ARTICLE 1 DEFINITIONS AND OTHER PROVISIONS OF GENERAL APPLICATION      1   
      Section 1.01        Definitions      1   
      Section 1.02        Other Definitions      14   
      Section 1.03        Rules of Construction      15   
      Section 1.04        Acts of Holders      16   
ARTICLE 2 THE NOTES      17   
      Section 2.01        Designation, Amount and Issuance of Notes      17   
      Section 2.02        Form of Notes      17   
      Section 2.03        Denomination of Notes      19   
      Section 2.04        Payments      19   
      Section 2.05        Execution and Authentication      22   
      Section 2.06        Registrar, Paying Agent and Conversion Agent      23   
      Section 2.07        Money Held in Trust      25   
      Section 2.08        Holder Lists      25   
      Section 2.09        Transfer and Exchange      25   
      Section 2.10        Transfer Restrictions.      30   
      Section 2.11        Replacement Notes      31   
      Section 2.12        Temporary Notes      32   
      Section 2.13        Cancellation      32   
      Section 2.14        Outstanding Notes      32   
      Section 2.15        Persons Deemed Owners      33   
      Section 2.16        Repurchases      33   
      Section 2.17        CUSIP and ISIN Numbers      33   
ARTICLE 3 REPURCHASE AT THE OPTION OF THE HOLDER      34   
      Section 3.01        Change of Control Permits Holders to Require the Company to Repurchase the Notes      34   
      Section 3.02        Change of Control Notice      35   
      Section 3.03        Change of Control Repurchase Notice      36   
      Section 3.04        Withdrawal of Change of Control Repurchase Notice      37   
      Section 3.05        Effect of Change of Control Repurchase Notice      37   
      Section 3.06        Notes Repurchased in Part      38   
      Section 3.07        Covenant to Comply With Securities Laws Upon Repurchase of Notes      39   
      Section 3.08        Deposit of Change of Control Repurchase Price      39   
      Section 3.09        Covenant Not to Repurchase Notes Upon Certain Events of Default      39   

 

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ARTICLE 4 COVENANTS      40   
      Section 4.01        Payment of Notes      40   
      Section 4.02        144A Information      40   
      Section 4.03        Reports      40   
      Section 4.04        Compliance Certificate      41   
      Section 4.05        Limitation on Indebtedness.      42   
      Section 4.06        Taxes      45   
      Section 4.07        Corporate Existence      45   
      Section 4.08        Stay, Extension and Usury Laws      45   
      Section 4.09        Further Instruments and Acts      46   
      Section 4.10        Determination of Equity Value      46   
      Section 4.11        Issuance of Conversion Shares      46   
  ARTICLE 5 CONSOLIDATION, MERGER AND SALE OF ASSETS      46   
      Section 5.01        Company May Consolidate, Merge or Sell Its Assets Only on Certain Terms      46   
      Section 5.02        Successor Substituted      47   
  ARTICLE 6 DEFAULTS AND REMEDIES      47   
      Section 6.01        Events of Default      47   
      Section 6.02        Acceleration      49   
      Section 6.03        Other Remedies      50   
      Section 6.04        Waiver of Past Defaults      50   
      Section 6.05        Control by Majority      50   
      Section 6.06        Limitation on Suits      51   
      Section 6.07        Rights of Holders To Receive Payment      51   
      Section 6.08        Collection Suit by Trustee      51   
      Section 6.09        Trustee May File Proofs of Claim      51   
      Section 6.10        Priorities      52   
      Section 6.11        Undertaking for Costs      52   
  ARTICLE 7 TRUSTEE      53   
      Section 7.01        Duties of Trustee      53   
      Section 7.02        Rights of Trustee      54   
      Section 7.03        Individual Rights of Trustee      55   
      Section 7.04        Trustee’s Disclaimer      55   
      Section 7.05        Notice of Defaults      55   
      Section 7.06        Compensation and Indemnity      56   
      Section 7.07        Replacement of Trustee      57   
      Section 7.08        Successor Trustee by Merger      58   
      Section 7.09        Eligibility; Disqualification      58   
      Section 7.10        Trustee’s Application for Instructions from the Company      58   

 

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ARTICLE 8 SATISFACTION AND DISCHARGE      58   
      Section 8.01        Satisfaction and Discharge      58   
ARTICLE 9 AMENDMENTS, SUPPLEMENTS AND WAIVERS      59   
      Section 9.01        Without Consent of Holders      59   
      Section 9.02        With Consent of Holders      60   
      Section 9.03        Execution of Supplemental Indentures      60   
      Section 9.04        Notices of Amendment or Supplemental Indentures      61   
      Section 9.05        Effect of Supplemental Indentures      61   
      Section 9.06        Revocation and Effect of Consents, Waivers and Actions      61   
      Section 9.07        Notation on, or Exchange of, Notes      61   
ARTICLE 10 SUBORDINATION      62   
      Section 10.01        Agreement to Subordinate      62   
      Section 10.02        Liquidation; Dissolution; Bankruptcy      62   
      Section 10.03        Default on Designated Senior Debt      62   
      Section 10.04        Acceleration of Notes      63   
      Section 10.05        When Distribution Must Be Paid Over      63   
      Section 10.06        Notice by the Company      64   
      Section 10.07        Subrogation      64   
      Section 10.08        Relative Rights      64   
      Section 10.09        Subordination May Not Be Impaired      64   
      Section 10.10        Distribution or Notice to Representative      65   
      Section 10.11        Reliance on Judicial Order or Certificate      65   
      Section 10.12        Rights of Trustee and Paying Agent      65   
      Section 10.13        Authorization to Effect Subordination      66   
      Section 10.14        Amendments      66   
  ARTICLE 11 CONVERSION      66   
      Section 11.01        Right To Convert Upon a Qualified PO      66   
      Section 11.02        Conversion Procedures      66   
      Section 11.03        Settlement Upon Conversion      68   
      Section 11.04        Common Stock Issued Upon Conversion      69   
      Section 11.05        Adjustment of Upside Trigger      70   
      Section 11.06        No Responsibility of Trustee, Conversion Agent and Paying Agent      71   
  ARTICLE 12 REDEMPTION AT THE OPTION OF THE COMPANY      72   
      Section 12.01        No Sinking Fund; Notes Not Redeemable Prior to Qualified PO or Change of Control      72   
      Section 12.02        Right to Redeem in Connection with a Qualified PO      72   
      Section 12.03        Right to Redeem Following a Change of Control      72   
      Section 12.04        General      72   

 

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      Section 12.05        Effect of Redemption Notice      74   
      Section 12.06        Deposit of Redemption Price      74   
      Section 12.07        Effect of Deposit      74   
      Section 12.08        Covenant Not to Redeem Notes Upon Certain Events of Default      74   
      Section 12.09        Repayment to the Company      74   
  ARTICLE 13 MISCELLANEOUS      75   
      Section 13.01        Notices      75   
      Section 13.02        Certificate and Opinion as to Conditions Precedent      76   
      Section 13.03        Statements Required in Certificate or Opinion      76   
      Section 13.04        Separability Clause      77   
      Section 13.05        Rules by Trustee      77   
      Section 13.06        Governing Law and Waiver of Jury Trial      77   
      Section 13.07        No Recourse Against Others      77   
      Section 13.08        Calculations      77   
      Section 13.09        Successors      77   
      Section 13.10        Multiple Originals      77   
      Section 13.11        Table of Contents; Headings      78   
      Section 13.12        Force Majeure      78   
      Section 13.13        Submission to Jurisdiction      78   
      Section 13.14        Legal Holidays      78   
      Section 13.15        No Security Interest Created      78   
      Section 13.16        Benefits of Indenture      78   
      Section 13.17        U.S.A. Patriot Act      78   
  Form of Note      A-1   
  Form of Restricted Stock Legend      B-1   

 

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INDENTURE, dated as of July 22, 2014, between Energy & Exploration Partners, Inc., a Delaware corporation (the “Company”), and U.S. Bank National Association, a national banking association, as trustee (“Trustee”).

For and in consideration of the premises and the purchase of the Notes by the Holders (each as defined below), each party agrees as follows for the benefit of the other party and for the equal and ratable benefit of the Holders of the Company’s 8.00% Convertible Subordinated Notes due 2019:

ARTICLE 1

DEFINITIONS AND OTHER PROVISIONS OF GENERAL APPLICATION

Section 1.01 Definitions.

Acquired Debt” means, with respect to any specified Person: (i) Indebtedness of any other Person existing at the time such other Person is merged with or into or became a Subsidiary of such specified Person, whether or not such Indebtedness is incurred in connection with, or in contemplation of, such other Person merging with or into, or becoming a Subsidiary of, such specified Person, and (ii) Indebtedness secured by a Lien encumbering any asset acquired by such specified Person.

Affiliate” means, with respect to any specified Person, any other Person who directly or indirectly through one or more intermediaries controls or is controlled by, or is under common control with such specified Person. The term “control” means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of a Person, whether through the ownership of voting securities, by contract or otherwise; and the terms “controlling” and “controlled” have meanings correlative of the foregoing.

Applicable Procedures” means, with respect to any transfer or transaction involving a Global Note or any beneficial interest therein, the rules and procedures of the Depositary, Euroclear and Clearstream for such Note, in each case to the extent applicable to such transfer or transaction and as in effect from time to time.

Attributable Debt” in respect of a sale and leaseback transaction means, at the time of determination, the present value of the obligation of the lessee for net rental payments during the remaining term of the lease included in such sale and leaseback transaction including any period for which such lease has been extended or may, at the option of the lessor, be extended. Such present value shall be calculated using a discount rate equal to the rate of interest implicit in such transaction, determined in accordance with GAAP. As used in the preceding sentence, the ‘‘net rental payments’’ under any lease for any such period shall mean the sum of rental and other payments required to be paid with respect to such period by the lessee thereunder, excluding any amounts required to be paid by such lessee on account of maintenance and repairs, insurance, taxes, assessments, water rates or similar charges. In the case of any lease that is terminable by the lessee upon payment of penalty, such net rental payment shall also include the amount of such penalty, but no rent shall be considered as required to be paid under such lease subsequent to the first date upon which it may be so terminated.

 

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Bankruptcy Law” means Title 11, United States Code, or any similar U.S. federal, state or non-U.S. bankruptcy, insolvency, receivership or similar law for the relief of debtors.

Board of Directors” means:

(1) with respect to a corporation, the board of directors of the corporation or any committee thereof duly authorized to act on behalf of such board;

(2) with respect to a partnership, the board of directors of the general partner of the partnership;

(3) with respect to a limited liability company, the managing member or members or any controlling committee of managing members thereof; and

(4) with respect to any other Person, the board or committee of such Person serving a similar function.

Board Resolution” means a copy of one or more resolutions certified by the Secretary or an Assistant Secretary of the Company to have been duly adopted by its Board of Directors and to be in full force and effect on the date of such certification, and delivered to the Trustee.

Business Day” means any day other than a Saturday, a Sunday or a day on which the Federal Reserve Bank of New York or banks in the city where the applicable place of payment is located is authorized or required by law or executive order to close or be closed.

Capital Lease Obligation” means, at the time any determination thereof is to be made, the amount of the liability of a Person in respect of a capital lease that would at that time be required to be capitalized on a balance sheet of such Person in accordance with GAAP.

Capital Stock” means:

(1) in the case of a corporation, corporate stock;

(2) in the case of an association or business entity, any and all shares, interests, participations, rights or other equivalents (however designated) of corporate stock;

(3) in the case of a partnership or limited liability company, partnership interests (whether general or limited) or membership interests; and

(4) any other interest or participation that confers on a Person (as defined below) the right to receive a share of the profits and losses of, or distributions of assets of, the issuing Person, but excluding from all of the foregoing any debt securities convertible into Capital Stock, whether or not such debt securities include any right of participation with Capital Stock.

Certificated Notes” means Notes that are in registered certificated form.

 

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Change of Control” means the occurrence at any time after the Notes are originally issued of any of the following:

(1) the direct or indirect sale, lease, transfer, conveyance or other disposition (other than by way of merger or consolidation), in one or a series of related transactions, of all or substantially all of the properties or assets of the Company and the Subsidiaries taken as a whole to any Person (including any “person” (as that term is used in Section 13(d)(3) of the Exchange Act)) other than any Permitted Holder;

(2) the adoption of a plan relating to the liquidation or dissolution of the Company; or

(3) the consummation of any transaction (including, without limitation, any merger or consolidation), the result of which is that any Person (including any “person” (as defined above)), other than any Permitted Holder, becomes the Beneficial Owner (as defined below), directly or indirectly, of more than 50% of the Voting Stock of the Company, measured by voting power rather than number of shares, membership interests, units or the like.

Notwithstanding the preceding, a conversion of a Person from a limited liability company, corporation, limited partnership or other form of entity to a limited liability company, corporation, limited partnership or other form of entity or an exchange of all of the outstanding Capital Stock in one form of entity for Capital Stock in another form of entity shall not constitute a Change of Control, so long as following such conversion or exchange the “persons” (as that term is used in Section 13(d)(3) of the Exchange Act) who Beneficially Owned the Capital Stock of the Company immediately prior to such transactions continue to Beneficially Own in the aggregate more than 50% of the Voting Stock of such entity, or continue to Beneficially Own sufficient Capital Stock in such entity to elect a majority of its directors, managers, trustees or other persons serving in a similar capacity for such entity, and, in either case no “person,” other than any Permitted Holder, Beneficially Owns more than 50% of the Voting Stock of such entity.

For purposes of this definition, the term “Beneficial Owner” has the meaning assigned to such term in Rule 13d-3 and Rule 13d-5 under the Exchange Act, except that in calculating the beneficial ownership of any particular “person” (as that term is used in Section 13(d)(3) of the Exchange Act), such “person” will be deemed to have beneficial ownership of all securities that such “person” has the right to acquire by conversion or exercise of other securities, whether such right is currently exercisable or is exercisable only after the passage of time. The terms “Beneficially Own” and “Beneficially Owned” have a corresponding meaning. Notwithstanding the foregoing, holders of the Company’s Equity Interests that are parties to the Stockholders Agreement shall not be deemed to be a “person” pursuant to Section 13(d)(3) solely by reason of the fact that they are parties to or bound by the terms of the Stockholders Agreement.

Change of Control Date” means the effective date of a Change of Control.

Clearstream” means Clearstream Banking, S.A.

Close of Business” means 5:00 p.m., New York City time.

Closing Date Equity Value” means the aggregate fair market value of the outstanding shares of Common Stock immediately following an Equity Sale (and, for the avoidance of doubt, after giving effect to such Equity Sale) (determined based on the sale price per share of Common Stock in the Equity Sale or, in the case of an Equity Sale involving Convertible Securities, the effective sale price per share of Common Stock after taking into consideration the purchase price

 

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of the Convertible Securities and any additional consideration to be paid by the holder of such Convertible Securities upon the exercise, exchange or conversion of such Convertible Securities into shares of Common Stock).

Commodity Agreement” means any oil or natural gas hedging agreement and other agreement or arrangement entered into in the ordinary course of business and designed to protect the Company or any Subsidiary against fluctuations in oil or natural gas prices.

Common Stock” means the common stock of the Company sold in the Qualified PO.

Company” means the party named as such in the first paragraph of this Indenture until a successor or assignee replaces it pursuant to the applicable provisions hereof and, thereafter, means the successor or assignee. The foregoing sentence will likewise apply to any such subsequent successor or assignee.

Company Order” means a written request or order signed in the name of the Company by any Officer.

Corporate Trust Office” means the designated office of the Trustee at which at any time its corporate trust business shall be administered, which office at the date hereof is located at 13737 Noel Road, Suite 800, Dallas, Texas 75240, or such other address as the Trustee may designate from time to time by written notice to the Holders, the Paying Agent, the Conversion Agent, the Registrar and the Company, or the designated corporate trust office of any successor Trustee (or such other address as such successor Trustee may designate from time to time by written notice to the Holders, the Paying Agent, the Conversion Agent, the Registrar and the Company).

Credit Facilities” means one or more debt facilities, indentures or commercial paper facilities (including, without limitation, the Term Loan), in each case with banks or other institutional lenders, providing for revolving credit loans, term loans, capital market financings, private placements, receivables financings (including through the sale of receivables to such lenders or to special purpose entities formed to borrow from such lenders against such receivables) or letters of credit or letter of credit guarantees, in each case, as amended, restated, modified, supplemented, extended, renewed, refunded, replaced or refinanced in whole or in part from time to time.

Currency Agreement” means any foreign currency exchange agreement, option or future contract or other similar agreement or arrangement entered into in the ordinary course of business and designed to protect against or manage the Company’s or any Subsidiaries’ exposure to fluctuations in foreign currency exchange rates.

Custodian” means any receiver, trustee, assignee, liquidator, custodian or similar official under any Bankruptcy Law.

Default” means any event which is, or after notice or passage of time or both would be, an Event of Default.

 

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Depositary” means The Depository Trust Company and its successors; provided that the Company may at any time, upon delivering written notice to the Holders, the Trustee, the Registrar, the Paying Agent and the Conversion Agent, appoint a successor Depositary.

Designated Senior Debt” means:

(1) any Indebtedness outstanding under the Term Loan or any other Indebtedness for money borrowed that is issued as a replacement or a refinancing of such Term Loan; and

(2) any other Senior Debt the principal amount of which is $35,000,000 or more and that has been designated by the Company in an Officers’ Certificate to the Trustee as “Designated Senior Debt.”

Disqualified Stock” means any Capital Stock that, by its terms (or by the terms of any security into which it is convertible, or for which it is exchangeable, in each case at the option of the holder thereof), or upon the happening of any event, matures or is mandatorily redeemable, for any consideration other than Capital Stock pursuant to a sinking fund obligation or otherwise, or is redeemable for any consideration other than Capital Stock at the option of the holder thereof, in whole or in part, on or prior to the date that is 91 days after the date on which the notes mature.

Equity Interests” means Capital Stock and all warrants, options or other rights to acquire Capital Stock (but excluding any debt security that is convertible into, or exchangeable for, Capital Stock).

Equity Value” means, with respect to the Company, as applicable, the enterprise value of such entity plus all cash and cash equivalents and short- and long-term investments of such entity less all Liabilities and minority interests of the Company, as determined in accordance with Section 4.10.

Euroclear” means Euroclear Bank, S.A./N.V., as operator of the Euroclear system.

Exchange Act” means the Securities Exchange Act of 1934, as amended.

Existing Indebtedness” means Indebtedness outstanding on the Issue Date, other than Indebtedness described under clauses (i), (iii) and (vi) of the definition of Permitted Indebtedness.

GAAP” means generally accepted accounting principles set forth in the opinions and pronouncements of the Accounting Principles Board of the American Institute of Certified Public Accountants and statements and pronouncements of the Financial Accounting Standards Board or in such other statements by such other entity as have been approved by a significant segment of the accounting profession, which are in effect from time to time.

Global Note Legend” means the legend identified as such in Exhibit A hereto.

Global Notes” means, individually and collectively, each of the permanent global notes that is in the form of the Note attached hereto as Exhibit A and that is registered in the name of the Depositary or the nominee of the Depositary and deposited with the Depositary, the nominee of the Depositary or a custodian appointed by the Depositary or the nominee of the Depositary.

 

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Guarantee” means, without duplication, any obligation, contingent or otherwise, of any Person directly or indirectly guaranteeing any Indebtedness of any other Person and any other obligation, direct or indirect, contingent or otherwise, of such Person:

(1) to purchase or pay (or advance or supply funds for the purchase or payment of) such Indebtedness of such other Person (whether arising by virtue of partnership arrangements, or by agreements to keepwell, to purchase assets, goods, securities or services, to take-or-pay or to maintain financial statement conditions or otherwise), or

(2) entered into for the purpose of assuring in any other manner the obligee of such Indebtedness of the payment therefor to protect such obligee against loss in respect thereof (in whole or in part);

provided, however, that the term ‘‘Guarantee’’ shall not include endorsements for collection or deposit in the ordinary course of business. The term ‘‘Guarantee’’ used as a verb has a corresponding meaning.

Guarantor” means any Subsidiary that Guarantees the Notes.

Hedging Obligations” means, with respect to any Person, the obligations of such Person under Currency Agreements, Interest Rate Agreements and Commodity Agreements.

Holder” or “Holders” means a Person or Persons in whose name a Note is registered in the Register.

Indebtedness” “ means, with respect to any specified Person, without duplication,

(1) all obligations of such Person, whether or not contingent, in respect of:

(i) the principal of and premium, if any, in respect of outstanding (A) Indebtedness of such Person for money borrowed and (B) Indebtedness evidenced by notes, debentures, bonds or other similar instruments for the payment of which such Person is responsible or liable;

(ii) all Capital Lease Obligations of such Person and all Attributable Debt in respect of sale and leaseback transactions entered into by such Person;

(iii) the deferred purchase price of property, which purchase price is due more than six months after the date of taking delivery of title to such property, including all obligations of such Person for the deferred purchase price of property under any title retention agreement, but excluding accrued expenses and trade accounts payable arising in the ordinary course of business; and

(iv) the reimbursement obligation of any obligor for the principal amount of any letter of credit, banker’s acceptance or similar transaction (excluding obligations with respect to letters of credit securing obligations (other than obligations described in clauses (i) through (iii) above)

 

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entered into in the ordinary course of business of such Person to the extent such letters of credit are not drawn upon or, if and to the extent drawn upon, such drawing is reimbursed no later than the tenth Business Day following receipt by such Person of a demand for reimbursement following payment on the letter of credit);

(2) all net obligations in respect of Currency Agreements, Interest Rate Agreements and Commodity Agreements, except to the extent such net obligations are otherwise included in this definition;

(3) all liabilities of others of the kind described in the preceding clause (1) or (2) that such Person has Guaranteed or that are otherwise its legal liability;

(4) Indebtedness (as otherwise defined in this definition) of another Person secured by a Lien on any asset of such Person, whether or not such Indebtedness is assumed by such Person, the amount of such obligations being deemed to be the lesser of (i) the full amount of such obligations so secured and (ii) the fair market value of such asset as determined in good faith by such specified Person;

(5) Disqualified Stock of such Person or a Subsidiary in an amount equal to the greater of the maximum mandatory redemption or repurchase price (not including, in either case, any redemption or repurchase premium) or the liquidation preference thereof;

(6) the aggregate preference in respect of amounts payable on the issued and outstanding shares of preferred stock of any of the Company’s Subsidiaries in the event of any voluntary or involuntary liquidation, dissolution or winding up (excluding any such preference attributable to such shares of preferred stock that are owned by such Person or any of its Subsidiaries; provided, that if such Person is the Company, such exclusion shall be for such preference attributable to such shares of preferred stock that are owned by the Company or any of its Subsidiaries); and

(7) any and all deferrals, renewals, extensions, refinancings and refundings (whether direct or indirect) of, or amendments, modifications or supplements to, any liability of the kind described in any of the preceding clauses (1), (2), (3), (4), (5), (6) or this clause (7), whether or not between or among the same parties, and to the extent that any of the preceding items (other than in respect of letters of credit and Hedging Obligations) would appear as a liability upon a balance sheet of the specified Person prepared accordance with GAAP.

Notwithstanding the foregoing, “Indebtedness” shall not include:

(a) accrued expenses, royalties and trade payables;

(b) contingent obligations incurred in the ordinary course of business;

(c) asset-retirement obligations or obligations in respect of reclamation and workers’ compensation (including pensions and retiree medical care) that are not overdue by more than 90 days; or

(d) in-kind obligations relating to net oil or natural gas balancing positions arising in the ordinary course of business.

 

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For purposes hereof, the maximum fixed repurchase price of any Disqualified Stock which does not have a fixed repurchase price shall be calculated in accordance with the terms of such Disqualified Stock as if such Disqualified Stock were purchased on any date on which Indebtedness shall be required to be determined pursuant to the Indenture, and if such price is based upon, or measured by, the fair market value of such Disqualified Stock, such fair market value to be determined in good faith by the Board of Directors of the issuer of such Disqualified Stock.

Notwithstanding the foregoing, Indebtedness shall not include (i) any indebtedness that has been defeased in accordance with GAAP or defeased pursuant to the deposit of cash, U.S. government obligations and cash equivalents (sufficient to satisfy all obligations relating thereto at maturity or redemption, as applicable) in a trust or account created or pledged for the sole benefit of the holders of such indebtedness, in accordance with the terms of the instruments governing such indebtedness, or (ii) any obligation of a Person in respect of a farm-in agreement or similar arrangement whereby such Person agrees to pay all or a share of the drilling, completion or other expenses of an exploratory or development well (which agreement may be subject to a maximum payment obligation, after which expenses are shared in accordance with the working or participation interest therein or in accordance with the agreement of the parties) or perform the drilling, completion or other operation on such well in exchange for an ownership interest in an oil or gas property.

Indenture” means this Indenture, as amended or supplemented from time to time in accordance with the terms hereof.

Interest Rate Agreements” means interest rate agreements, interest rate cap agreements and interest rate collar agreements and other agreements or arrangements designed to protect such Person against fluctuations in interest rates, with respect to any Indebtedness that is permitted to be incurred under the Indenture.

Issue Date” means July 22, 2014.

Liabilities” means all short-term and long-term debt, losses related to mark-to-market of derivatives, current and deferred tax liabilities, and any other obligation for which monies are owed.

Lien” means, with respect to any asset, any mortgage, lien, pledge, charge, security interest or encumbrance of any kind in respect of such asset, whether or not filed, recorded or otherwise perfected under applicable law, including any conditional sale or other title retention agreement, any lease in the nature thereof, any option or other agreement to sell or give a security interest in any assets and any filing of or agreement to give any financing statement under the Uniform Commercial Code (or equivalent statutes) of any jurisdiction.

Net Cash Proceeds” with respect to the incurrence of any Indebtedness means the cash proceeds of such incurrence net of attorneys’ fees, accountants’ fees, underwriters’ or placement agents’ fees, listing fees, discounts or commissions and brokerage, consultant and other fees and charges actually incurred in connection with such issuance or sale and net of taxes paid or payable as a result of such incurrence.

 

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Non-Recourse Purchase Money Indebtedness” means Indebtedness (other than Capital Lease Obligations) of the Company or any Guarantor incurred in connection with the acquisition by the Company or such Guarantor of assets used in the Oil and Gas Business (including office buildings and other real property used by the Company or such Guarantor in conducting its operations) with respect to which:

(1) the holders of such Indebtedness agree that they will look solely to the assets so acquired that secure such Indebtedness, and neither the Company nor any Subsidiary (a) is directly or indirectly liable for such Indebtedness or (b) provides credit support, including any undertaking, Guarantee, agreement or instrument that would constitute Indebtedness (other than the grant of a Lien on such acquired assets); and

(2) no default or event of default with respect to such Indebtedness would cause, or permit (after notice or passage of time or otherwise), any holder of any other Indebtedness of the Company or a Guarantor to declare a default or event of default on such other Indebtedness or cause the payment, repurchase, redemption, defeasance or other acquisition or retirement for value thereof to be accelerated or payable prior to any scheduled principal payment, scheduled sinking fund payment or maturity.

Notes” means any of the Company’s 8.00% Convertible Subordinated Notes due 2019 issued under this Indenture.

Offering Memorandum” means the Offering Memorandum, dated July 10, 2014, relating to the offering of the Notes.

Officer” means the Chairman of the Board, the Vice Chairman, the Chief Executive Officer, the President, the Chief Financial Officer, any Executive Vice President, any Senior Vice President, any Vice President, the Chief Accounting Officer, the Treasurer or the Secretary of the Company.

Officers’ Certificate” means a written certificate containing the information specified in Sections 13.02 and 13.03 hereof, signed in the name of the Company by any two Officers of the Company, and delivered to the Trustee; provided, that, if such certificate is given pursuant to Section 4.04 hereof, (i) one of the Officers signing such certificate must be the Chief Executive Officer, the Chief Financial Officer or the Chief Accounting Officer of the Company and (ii) such certificate need not contain the information specified in Sections 13.02 and 13.03 hereof.

Oil and Gas Business” means:

(1) the acquisition, exploration, exploitation, development, servicing, operation or disposition of interests in, or obtaining production from, oil, natural gas or other hydrocarbon properties;

(2) the gathering, marketing, treating, processing (but not refining), storage, selling or transporting of any production from such interests or properties; or

(3) any activity that is ancillary, necessary or appropriate to facilitate, or that is incidental to, the activities described in clauses (1) and (2) of this definition.

 

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Open of Business” means 9:00 a.m., New York City time.

Opinion of Counsel” means a written opinion containing the information specified in Sections 13.02 and 13.03 hereof, from legal counsel and delivered to the Trustee. The counsel may be an employee of, or counsel to, the Company.

Permitted Holder” means any of (i) Mr. B. Hunt Pettit and any members of his immediate family and their respective Affiliates, (ii) Highbridge Principal Strategies, LLC and its Affiliates, and (iii) Apollo Investment Corporation and its Affiliates.

Permitted Refinancing Indebtedness” means any Indebtedness of the Company or any Subsidiaries issued in exchange for, or the Net Cash Proceeds of which are used to extend, refinance, renew, replace, defease or refund other Indebtedness of the Company or any Subsidiaries (other than intercompany Indebtedness); provided that:

(1) the principal amount (or accreted value, if applicable) of such Permitted Refinancing Indebtedness does not exceed the principal amount of (or accreted value, if applicable), plus premium, if any, and accrued and unpaid interest on the Indebtedness so extended, refinanced, renewed, replaced, defeased or refunded (plus the amount of reasonable expenses incurred in connection therewith);

(2) (a) if the final maturity date of the Indebtedness being extended, refinanced, renewed, replaced, deferred or refunded is earlier than the final maturity date of the Notes, the Permitted Refinancing Indebtedness has a final maturity date no earlier than the final maturity date of the Indebtedness being extended, refinanced, renewed, replaced, deferred or refunded; or

(b) if the final maturity date of the Indebtedness being extended, refinanced, renewed, replaced, deferred or refunded is later than the final maturity date of the Notes, the Permitted Refinancing Indebtedness has a final maturity date at least 91 days later than the final maturity date of the Notes;

(3) the Permitted Refinancing Indebtedness has a Weighted Average Life to Maturity at the time such Permitted Refinancing Indebtedness is incurred that is equal to or greater than the Weighted Average Life to Maturity of the Indebtedness being extended, refinanced, renewed, replaced, deferred or refunded;

(4) if the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded is subordinated in right of payment to the Notes or a Guarantee, such Permitted Refinancing Indebtedness is subordinated in right of payment to the Notes or such Guarantee on terms at least as favorable, taken as a whole, to the holders of Notes as those contained in the documentation governing the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded;

(5) such Indebtedness is not incurred by a Subsidiary if the Company is the obligor on the Indebtedness being extended, refinanced, renewed, replaced, defeased or refunded; provided, however, that a Subsidiary that is also a Guarantor may Guarantee Permitted Refinancing Indebtedness incurred by the Company, whether or not such Subsidiary was an obligor or guarantor of the Indebtedness being extended, refinanced, renewed, replaced, defeased or

 

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refunded; provided further, however, that if such Permitted Refinancing Indebtedness is subordinated to the Notes, such Guarantee shall be subordinated to such Subsidiary’s Guarantee to at least the same extent; and

(6) if the Indebtedness being extended, refinanced, renewed, replaced, defeased, or refunded is Non-Recourse Purchase Money Indebtedness, such Permitted Refinancing Indebtedness satisfies clauses (1) and (2) of the definition of “Non-Recourse Purchase Money Indebtedness.”

Person” means any individual, corporation, partnership, joint venture, association, joint-stock company, trust, unincorporated organization, limited liability company or government or other entity.

Pre-Qualified PO Share Number” means the number of shares of Common Stock outstanding immediately prior to the Qualified PO without giving effect to any conversion of the Notes but after giving effect to the conversion or exchange of any other securities that are convertible or exchangeable into Common Stock and any stock splits, reverse stock splits or stock dividends that occur prior to the consummation of the Qualified PO.

Pro Rata Portion” means, with respect to the number of Conversion Shares deliverable to any Holder upon conversion, the product of (A) the aggregate number of Conversion Shares determined in accordance with Section 11.03(a) for all Notes outstanding at the time of the closing of the Qualified PO and (B) a fraction, the numerator of which is the principal amount of the Notes held by such Holder and the denominator of which is the Qualified PO Principal Amount.

Qualified PO” means the first public offering of the Common Stock (a) in which the aggregate gross proceeds to the Company and the stockholders selling such Common Stock, if any, equal or exceed $400,000,000 and (b) following such offering, such Common Stock is listed on a U.S. national securities exchange. For the avoidance of doubt, if a Qualified PO does not successfully close, it shall not prevent a future public offering from qualifying and being treated as a “Qualified PO.”

Qualified PO Filing Date” means the date of the first filing of a registration statement in connection with a Qualified PO.

Qualified PO Principal Amount” means the aggregate principal amount of the Notes outstanding on the closing date of the Qualified PO.

Registration Rights Agreement” means the Registration Rights Agreement, dated as of July 22, 2014, among the Company and Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC/Seaport Group Securities, LLC, as such agreement may be amended, modified or supplemented from time to time and, with respect to any additional Notes, one or more registration rights agreements among the Company and the initial purchasers thereof, as such agreement(s) may be amended, modified or supplemented from time to time, relating to rights provided by the Company to the purchasers of additional Notes to register Conversion Shares under the Securities Act.

 

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Related Securities” means any options or warrants or other rights to acquire Conversion Shares or any securities exchangeable or exercisable for or convertible into Conversion Shares, or to acquire other securities or rights ultimately exchangeable or exercisable for or convertible into Conversion Shares.

Representative” means the indenture trustee or other trustee, agent or representative for any Senior Debt.

Responsible Officer” means any officer within the corporate trust department of the Trustee (or any successor group of the Trustee) with direct responsibility for the administration of this Indenture and also means, with respect to a particular corporate trust matter hereunder, any other officer of the Trustee to whom such matter is referred because of his or her knowledge of and familiarity with the particular subject.

Restricted Notes Legend” means the legend identified as such set forth in Exhibit A hereto, or any other similar legend indicating the restricted status of the Notes under Rule 144.

Restricted Stock Legend” means a legend in the form set forth in Exhibit B hereto or any other similar legend indicating the restricted status of the Common Stock under Rule 144.

Rule 1-02(w)” means Rule 1-02(w) of Regulation S-X promulgated under the Securities Act, as such regulation is in effect on the date of this Indenture

Rule 144” means Rule 144 under the Securities Act (or any successor provision), as it may be amended from time to time.

Rule 144A” means Rule 144A under the Securities Act (or any successor provision), as it may be amended from time to time.

SEC” means the Securities and Exchange Commission.

Securities Act” means the Securities Act of 1933, as amended.

Senior Debt” means:

(1) the Company’s obligations for money borrowed or purchased including without limitation the Designated Senior Debt;

(2) Indebtedness evidenced by bonds, debentures, notes or similar instruments;

(3) obligations associated with derivative products including but not limited to securities contracts, foreign currency exchange contracts, swap agreements (including interest rate and foreign exchange rate swap agreements), cap agreements, floor agreements, collar agreements, interest rate agreements, foreign exchange rate agreements, options, commodity futures contracts, commodity option contracts and similar financial instruments; and

(4) debt of others described in the preceding clauses that the Company has guaranteed or for which the Company is otherwise liable,

 

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in each case unless, in any case, in the instrument creating or evidencing any such indebtedness or obligation, or pursuant to which the same is outstanding, it is provided that such indebtedness or obligation is not superior in right of payment to the Notes or to other debt that is pari passu with or subordinate to the Notes.

Notwithstanding anything to the contrary in the preceding, Senior Debt will not include:

(1) any liability for federal, state, local or other taxes owed or owing by the Company;

(2) any intercompany indebtedness of the Company or any of the Subsidiaries to the Company or any of its Affiliates;

(3) any trade payables; or

(4) indebtedness which is classified as non-recourse in accordance with GAAP or any unsecured claim arising in respect thereof by reason of the application of section 1111(b)(1) of the Bankruptcy Code.

Significant Subsidiary” means any Subsidiary that is a “significant subsidiary” of the Company within the meaning of Rule 1-02(w).

Stockholders Agreement” means the Second Amended and Restated Stockholders Agreement among the Company and the holders of Equity Interests in the Company dated as of July 10, 2014, as amended, restated or supplemented from time to time.

Subsidiary” means any subsidiary of the Company. A “subsidiary” of any Person means: (i) a corporation a majority of whose Voting Stock is at the time, directly or indirectly owned by such Person, by one or more subsidiaries of such Person or by such Person and one or more subsidiaries of such Person; or (ii) a partnership, joint venture, limited liability company or similar entity, in which such Person or a subsidiary of such Person is, at the date of determination, in the case of a partnership, a general or limited partner of such partnership, and, in the case of each of the foregoing entities, is entitled to receive more than 50 percent of the assets of such entity upon its dissolution.

Term Loan” means that certain Credit Agreement, dated as of July 22, 2014, among the Company, Energy & Exploration Partners, LLC, as borrower, the Lenders party thereto and Credit Suisse AG, Cayman Islands Branch, as Administrative and Collateral Agent, together with any related notes, guarantees, collateral documents, instruments and agreements executed in connection therewith, and, in each case, as amended, restated, modified, renewed, refunded, replaced in any manner (whether upon or after termination or otherwise) or refinanced in whole or in part from time to time.

Transfer” means, with respect to any Note or share of Common Stock that bears, or is required to bear, the Restricted Stock Legend, any sale, pledge, transfer, loan, hypothecation or other disposition of such Note or share of Common Stock, as the case may be.

Transfer Agent” means an entity acting in its capacity as the transfer agent for the Common Stock.

 

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Trustee” means the party named as the “Trustee” in the first paragraph of this Indenture until a successor replaces it pursuant to the applicable provisions of this Indenture and, thereafter, means such successor. The foregoing sentence will likewise apply to any such subsequent successor or successors.

Upside Trigger” means, initially, a notional Equity Value of the Company of $900,000,000, subject to adjustment pursuant to Section 11.05 hereof.

Voting Stock” of any specified Person as of any date means the Capital Stock of such Person that is at the time entitled to vote in the election of the Board of Directors of such Person.

Weighted Average Life to Maturity” means, when applied to any Indebtedness at any date, the number of years obtained by dividing:

(1) the sum of the products obtained by multiplying (a) the amount of each then remaining installment, sinking fund, serial maturity or other required payments of principal, including payment at final maturity, in respect thereof, by (b) the number of years (calculated to the nearest one-twelfth) that will elapse between such date and the making of such payment; by

(2) the then outstanding principal amount of such Indebtedness.

Section 1.02 Other Definitions.

 

Term:

  

Defined in:

Act    1.04
Agent Members    2.02(c)
Applicable Conversion Price    11.03(a)(i)(A)
Applicable Premium    3.01(b)(i)
Change of Control Notice    3.02(a)
Change of Control Notice Date    3.02(a)
Change of Control Redemption    12.03
Change of Control Repurchase Date    3.01(c)
Change of Control Repurchase Notice    3.03(a)(i)
Change of Control Repurchase Price    3.01(b)
Conversion Agent    2.06(a)
Conversion Date    11.02(a)
Conversion Deadline    11.01(a)
Conversion Notice    11.02(a)
Conversion Shares    11.01(a)
Convertible Securities    11.05(a)
Defaulted Amount    2.04(c)
Default Interest    2.04(c)
Equity Sale    11.05(a)
Event of Default    6.01(a)
Interest Rate    2.04(a)(ii)
Interest Payment Date    2.04(a)(ii)
Lock-up Period    11.02(e)

 

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Term:

  

Defined in:

Maturity Date    2.04(a)(i)
Paying Agent    2.06(a)
Payment Blockage Notice    10.03(a)(ii)
Permitted Indebtedness    4.05(a)
Redemption Date    12.04(a)(ii)
Redemption Notice    12.04(a)
Redemption Notice Date    12.04(a)
Redemption Price    12.04(a)(iii)
Register    2.06(a)
Registrar    2.06(a)
Regular Record Date    2.04(a)(ii)
Regulation S Global Notes    2.10(c)(i)
Reorganization Event    5.01
Reorganization Successor Corporation    5.01(a)(ii)
Reports    4.03(a)
Restricted Period    2.10(c)(i)
Rule 144A Global Notes    2.10(c)(i)
Qualified PO Redemption    12.02
Qualified PO Redemption Right    12.02
Qualified PO Redemption Notice    12.02
Qualified PO Revocation Notice    12.02
Scheduled Interest Rate Increase    2.04(a)(ii)
Special Record Date    2.04(c)(i)
Terminal Value    2.04(a)(i)
Temporary Notes    2.12

Section 1.03 Rules of Construction.

Unless the context otherwise requires:

(1) a term has the meaning assigned to it;

(2) an accounting term not otherwise defined has the meaning assigned to it and will be construed in accordance with GAAP;

(3) “or” is not exclusive;

(4) “including” means including, without limitation;

(5) words in the singular include the plural, and words in the plural include the singular;

(6) “will” shall be interpreted to express a command;

(7) any reference to an “Article”, “Section” or “clause” refers to an Article, Section or clause, as the case may be, of this Indenture;

 

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(8) references to sections of, or rules under, the Securities Act or the Exchange Act shall be deemed to include substitute, replacement or successor sections or rules adopted by the SEC from time to time;

(9) all references to $, dollars, cash payments or money refer to United States currency; and

(10) all references to interest on the Notes will not include any Default Interest payable on a Defaulted Amount pursuant to the terms of Section 2.04 hereof.

Section 1.04 Acts of Holders. Any request, demand, authorization, direction, notice, consent, waiver or other action provided by this Indenture to be given or taken by Holders may be embodied in and evidenced by one or more instruments of substantially similar tenor signed by such Holders in person or by an agent duly appointed in writing; and, except as herein otherwise expressly provided, such action will become effective when such instrument or instruments are delivered to the Trustee and to the Company. Such instrument or instruments (and the action embodied therein and evidenced thereby) are herein sometimes referred to as the “Act” of Holders signing such instrument or instruments. Proof of execution of any such instrument or of a writing appointing any such agent will be sufficient for any purpose of this Indenture and conclusive in favor of the Trustee and the Company, if made in the manner provided in this Section 1.04.

The fact and date of the execution by any Person of any such instrument or writing may be proved by the affidavit of a witness of such execution or by a certificate of a notary public or other officer authorized by law to take acknowledgments of deeds, certifying that the individual signing such instrument or writing acknowledged to such officer the execution thereof. Where such execution is by a signer acting in a capacity other than such signer’s individual capacity, such certificate or affidavit will also constitute sufficient proof of such signer’s authority. The fact and date of the execution of any such instrument or writing, or the authority of the Person executing the same, may also be proved in any other manner that the Trustee deems sufficient.

Any request, demand, authorization, direction, notice, consent, waiver or other Act of the Holder of any Note will bind every future Holder of the same Note and the Holder of every Note issued upon the registration of transfer thereof or in exchange therefor or in lieu thereof in respect of anything done, omitted or suffered to be done by the Trustee, the Company, the Paying Agent, the Conversion Agent or the Registrar in reliance thereon, whether or not notation of such action is made upon such Note.

If the Company solicits from the Holders any request, demand, authorization, direction, notice, consent, waiver or other Act, the Company may, at its option, by or pursuant to a Board Resolution, fix in advance a record date for the determination of Holders entitled to give such request, demand, authorization, direction, notice, consent, waiver or other Act, but the Company will have no obligation to do so. If such a record date is fixed, such request, demand,

 

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authorization, direction, notice, consent, waiver or other Act may be given before or after such record date, but only the Holders of record at the Close of Business on such record date will be deemed to be Holders for the purposes of determining whether Holders of the requisite proportion of outstanding Notes have authorized or agreed or consented to such request, demand, authorization, direction, notice, consent, waiver or other Act, and, for that purpose, the outstanding Notes will be computed as of such record date; provided that no such authorization, agreement or consent by the Holders on such record date will be deemed effective unless it will become effective pursuant to the provisions of this Indenture not later than six months after the record date.

ARTICLE 2

THE NOTES

Section 2.01 Designation, Amount and Issuance of Notes.

(a) The Notes will be designated as “8.00% Convertible Subordinated Notes due 2019.” The initial aggregate principal amount of Notes to be issued, authenticated and delivered on the Issue Date under this Indenture is $375,000,000. From time to time, the Company may issue and execute, and the Trustee may authenticate, Notes delivered upon registration or transfer of, or in exchange for, or in lieu of, other Notes pursuant to Sections 2.09, 2.11, 2.12 and 3.06 hereof. In addition, the Company may issue an unlimited aggregate principal amount of additional Notes in accordance with Section 2.01(b) hereof.

(b) Without the consent of any Holder, and notwithstanding anything to the contrary in Sections 2.01(a) or 2.05 hereof, the Company may increase the aggregate principal amount of the Notes issued under this Indenture by reopening this Indenture and issuing additional Notes with the same terms as the initial Notes (except, to the extent applicable, with respect to the date as of which interest shall begin to accrue on such additional Notes), which Notes will, subject to the foregoing, be considered to be part of the same series of Notes as those initially issued hereunder; provided, however, that if any such additional Notes are not fungible with other Notes issued hereunder for federal income tax purposes, then such additional Notes shall have a separate CUSIP number. Prior to issuing any such additional Notes, the Company will deliver to the Trustee a Company Order, an Officers’ Certificate and an Opinion of Counsel, which Officers’ Certificate and Opinion of Counsel will (i) address any matters required to be addressed under Section 13.03 hereof, (ii) include a statement that the form and the terms of such Notes has been established in conformity with the provisions of this Indenture and (iii) include a statement that the Notes when authenticated and delivered by the Trustee and issued by the Company in the manner and subject to any conditions specified in such Officers’ Certificate or Opinion of Counsel, will constitute valid and legally binding obligations of the Company, enforceable in accordance with their terms, subject to bankruptcy, insolvency, reorganization and other laws of general applicability relating to or affecting the enforcement of creditors’ rights and to general equity principles.

Section 2.02 Form of Notes.

(a) General. The Notes will be substantially in the form of Exhibit A hereto, but may include any notations, legends or endorsements required by any applicable law (or regulation promulgated thereunder), stock exchange rule, agreement to which the Company is subject or usage, or any insertions, omissions or other variations otherwise permitted or required by this Indenture. Whenever any such notation, legend or endorsement, or any such insertion, omission or other variation is applicable to a Note, the Company will provide such notation, legend or endorsement, or such insertion, omission or other variation to the Trustee in writing.

 

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Each Note will bear a Trustee’s certificate of authentication substantially in the form set forth in Exhibit A hereto.

Notes that are Global Notes will bear the Global Note Legend and the “Schedule of Increases and Decreases of Global Note” attached thereto.

Notes will bear the Restricted Notes Legend.

The terms and provisions contained in the Notes will constitute, and are hereby expressly made, a part of this Indenture and, to the extent applicable, the Company and the Trustee, by their execution and delivery of this Indenture, expressly agree to such terms and provisions and to be bound thereby. However, to the extent that any provision of any Note conflicts with the express provisions of this Indenture, the provisions of this Indenture will govern and control.

(b) Initial and Subsequent Notes. The Notes initially will be issued in global form, registered in the name of Cede & Co., as the nominee of the Depositary, and deposited with the Trustee, at its Corporate Trust Office, as custodian for the Depositary. Except to the extent provided in Section 2.09(c) hereof, all Notes will be represented by one or more Global Notes.

(c) Global Notes. Each Global Note will represent the aggregate principal amount of then outstanding Notes endorsed thereon and provide that it represents such aggregate principal amount of then outstanding Notes, which aggregate principal amount may, from time to time, be reduced or increased to reflect transfers, exchanges, conversions, redemptions or repurchases by the Company.

Only the Trustee, or the custodian holding such Global Note for the Depositary at the direction of the Trustee, may endorse a Global Note and/or, in the case of the Trustee, adjust the balance on the Register in accordance with its internal procedures, to reflect the amount of any increase or decrease in the aggregate principal amount of then outstanding Notes represented thereby, and whenever the Holder of a Global Note delivers instructions to the Trustee to increase or decrease the aggregate principal amount of then outstanding Notes represented by a Global Note in accordance with Section 2.09 hereof, the Trustee, or the custodian holding such Global Note for the Depositary, at the direction of the Trustee, will endorse such Global Note and/or, in the case of the Trustee, adjust the balance of the Register in accordance with its internal procedures, to reflect such increase or decrease in the aggregate principal amount of then outstanding Notes represented thereby. None of the Trustee, the Company or any agent of the Trustee or the Company will have any responsibility or bear any liability for any aspect of the records relating to, or payments made on account of, the ownership of any beneficial interest in a Global Note or with respect to maintaining, supervising or reviewing any records relating to such beneficial interest.

Neither any member of, or participant in, the Depositary, Euroclear or Clearstream (collectively, the “Agent Members”) nor any other Person on whose behalf an Agent Member may act will have any rights under this Indenture with respect to any Global Note or under such Global Note, and the Company, the Trustee and any agent of the Company or the Trustee, may, for all purposes, treat the Depositary, or its nominee, if any, as the absolute owner and Holder of such Global Note.

 

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The Holder of a Global Note may grant proxies and otherwise authorize any Person, including Agent Members and Persons that may hold interests through Agent Members, to take any action that such Holder is entitled to take under this Indenture or the Notes with respect to such Global Note, and, notwithstanding the foregoing, nothing herein will prevent the Company, the Trustee, the Paying Agent or any agent of the Company, the Trustee or the Paying Agent from giving effect to any written certification, proxy or other authorization furnished by such Holder or impair, as between the Depositary, its Agent Members and any other Person on whose behalf an Agent Member may act, the operation of their respective customary practices governing the exercise of the rights of a Holder of any interest in any Global Note.

Neither the Trustee nor any of the Paying Agent, Registrar, Conversion Agent or any other agent of the Trustee shall have any responsibility or liability for the payment of amounts to owners of beneficial interests in a Global Note for any aspect of the records relating to or payments made on account of those interests by the Depositary or for maintaining, supervising or reviewing any records of the Depositary relating to those interests.

Section 2.03 Denomination of Notes. The Notes will be issuable in minimum denominations of $1,000.00 principal amount and in integral multiples of $1,000 in excess thereof.

Section 2.04 Payments.

(a) General.

(i) Terminal Value Payment at Maturity or Upon Certain Events. Unless earlier converted, redeemed or repurchased pursuant to any of Sections 3.05(c), 11.03 or 12.07 hereof, the Notes will mature on July 1, 2019 (the “Maturity Date”). On the Maturity Date, each Holder will be entitled to, and the Company will pay or cause the Paying Agent to pay each Holder, a cash amount equal to the product of (w) the principal amount of Notes held by such Holder on the Maturity Date and (x) the Applicable Premium as of the Maturity Date (calculated pursuant to Section 3.01(b) as if the Maturity Date was the Change of Control Date for purposes of that calculation), together with all accrued and unpaid interest on such Notes to, but not including, the Maturity Date. In addition, notwithstanding anything in this Indenture to the contrary, in the event of the liquidation, dissolution or winding up of the Company, including, without limitation, any such event constituting an Event of Default specified in Section 6.01(a)(ix) (but not, for the avoidance of doubt, any such event complying with Section 5.01), each Holder will be entitled to, and the Company will pay or cause the Paying Agent to pay each Holder, a cash amount equal to the product of (y) the principal amount of Notes held by such Holder on the effective date of such event and (z) the Applicable Premium as of such effective date (calculated pursuant to Section 3.01(b) as if such effective date was the Change of Control Date for purposes of that calculation), together with all accrued and unpaid interest on such Notes to, but not including, such effective date. The amount payable under this Section 2.04(a)(i) is referred to herein as the “Terminal Value.”

 

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(ii) Payment of Interest. Each Note will accrue interest at a rate (the “Interest Rate”) equal to 8.00% per annum from the most recent date to which interest has been paid or duly provided for, or, if no interest has been paid or duly provided for, the Issue Date (or such other date provided for in Section 2.01(b) with respect to Notes issued in accordance with such Section) until, subject to the provisions of Section 2.04(c), the date the principal amount of such Note is converted, paid or deemed paid, as the case may be, pursuant to clause (i) of this Section 2.04(a) or any of Sections 3.05, 11.03 or 12.07 hereof; provided that the Interest Rate on the Notes will increase by 0.50% per annum effective as of the Interest Payment Date falling on July 1, 2015 and on each Interest Payment Date thereafter (a “Scheduled Interest Rate Increase”) if a preliminary prospectus under the Securities Act with a bona fide price range in connection with a Qualified PO has not been filed by each such Interest Payment Date and, in each case, such Qualified PO has not priced within 60 days after the date of such Scheduled Interest Rate Increase. The Company shall notify the Trustee of such Scheduled Interest Rate Increase in an Officers’ Certificate.

Interest will be payable semi-annually in arrears on January 1 and July 1 of each year (each, an “Interest Payment Date”), beginning January 1, 2015 (or such other date provided for in Section 2.01(b) with respect to Notes issued in accordance with such Section), to the Holder of each such Note as of the Close of Business (whether or not a Business Day) on the December 15 or June 15, as the case may be, immediately preceding the relevant Interest Payment Date (each such date, a “Regular Record Date”). Interest will be computed on the basis of a 360-day year comprised of twelve 30-day months.

Interest accruing on the Notes will be payable on each Interest Payment Date entirely in cash.

(iii) Method of Payment. The Company will pay or cause the Paying Agent to pay any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and interest on, any Global Note to the Depositary by wire transfer of immediately available funds on the relevant payment date.

The Company will pay or cause the Paying Agent to pay any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and interest on any Certificated Note in cash to the applicable Holder of such Note at the office of the Paying Agent on the relevant payment date or, at the option of the Company, through the Paying Agent by check mailed to the Holder of such Note at its address set forth in the register of Holders.

The Company will pay or cause the Paying Agent to pay interest due on an Interest Payment Date on any Certificated Note (i) to any Holder of an aggregate principal amount of Notes less than or equal to $5,000,000, by check mailed to such Holder’s registered address, and (ii) to any Holder of an aggregate principal amount of Notes greater than $5,000,000, either by check mailed to such Holder’s registered address or, upon application by such Holder to the Registrar not later than five days prior to the Regular Record Date relating to such Interest Payment Date, a written request to the Registrar that the Company makes such payments by wire transfer to an account of such Holder within the United States, by wire transfer of immediately available funds to such account, which request shall remain in effect until such Holder notifies, in writing, the Registrar to the contrary.

 

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If any Interest Payment Date, the date for payment of amounts in respect of conversions, the Maturity Date or a Change of Control Repurchase Date falls on a day that is not a Business Day, the required payment will be made on the next succeeding Business Day and no interest on such payment will accrue as a result of such delay.

(b) Interest Rights Preserved. Subject to the provisions of Section 2.04(c) hereof, and, to the extent applicable, Sections 2.09 and 2.11 hereof, each Note delivered under this Indenture upon registration of transfer of, or in exchange for, or in lieu of, any other Note will carry any rights to the payment and accrual of interest that were carried by the relevant surrendered Note, Notes or portion(s) thereof.

(c) Defaulted Amounts. Whenever any principal or interest payable on a Note (including any Change of Control Repurchase Price, Redemption Price or Terminal Value, if applicable) has become due and payable on the Maturity Date, upon repurchase, redemption or declaration of acceleration or otherwise, but the Company fails to punctually pay or duly provide for such amount (any such amount, a “Defaulted Amount”), such Defaulted Amount will forthwith cease to be payable to the Holder of such Note on the relevant payment date by virtue of its having been due such payment on such payment date, but will instead, to the extent permitted under applicable law, accrue interest (“Default Interest”) at a rate equal to the then prevailing Interest Rate plus 1% per annum from, and including, such payment date and to, but excluding, the date on which such Defaulted Amount is paid by the Company in accordance with either clause (i) or (ii) below.

(i) The Company may elect to pay any Defaulted Amount and Default Interest on such Defaulted Amount to the Persons in whose names the Notes (or their respective predecessor Notes) are registered at the Close of Business on a special record date for the payment of such Defaulted Amount and Default Interest (a “Special Record Date”) fixed in accordance with the following procedures:

(A) At least 30 days before the date on which the Company proposes to pay such Defaulted Amounts and Default Interest thereon, the Company will deliver to the Trustee written notice in the form of an Officers’ Certificate of (I) the proposed payment date for such Defaulted Amounts and Default Interest thereon and (II) the aggregate amount of such Defaulted Amounts and Default Interest thereon.

(B) Simultaneously with delivering such notice to the Trustee, the Company will either (I) deposit with the Trustee an amount of money, in immediately available funds, equal to the aggregate amount of such Defaulted Amounts and Default Interest thereon, or (II) take other actions that the Trustee deems reasonably satisfactory to ensure that an amount of money, in immediately available funds, equal to the aggregate of such Defaulted Amounts and Default Interest thereon will be deposited with the Trustee by 10:00 a.m., New York City time, on the proposed payment date, and in either case, upon receipt of such money, the Trustee will hold such money in trust for the benefit of the Persons entitled to such Defaulted Amounts and Default Interest pursuant to this Section 2.04(c)(i).

 

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(C) Upon (i) receipt of such notice and (ii) the Company’s depositing such money or taking such other actions reasonably satisfactory to the Trustee, the Company will promptly fix a Special Record Date for the payment of such Defaulted Amounts and Default Interest thereon, which Special Record Date will be not more than 15 calendar days and not less than 10 days prior to the proposed payment date, and notify the Trustee in writing of the Special Record Date. The Trustee will then, in the name and at the expense of the Company, deliver notice to each Holder specifying such Special Record Date and the date on which such Defaulted Amounts and Default Interest thereon will be paid by the Company.

(D) After such notice has been delivered by the Trustee, such Defaulted Amounts and Default Interest thereon will be paid to the Persons in whose names the Notes (or their respective predecessor Notes) are registered at the Close of Business on the Special Record Date specified in such notice and such Defaulted Amounts and Default Interest thereon will no longer be payable pursuant to the following clause (ii) of this Section 2.04(c)(i).

(ii) The Company may pay any Defaulted Amounts and Default Interest on such Defaulted Amounts in any other lawful manner that is not inconsistent with the requirements of any securities exchange or automated quotation system on which the Notes are then listed (or, if applicable, have been approved for listing) or designated for issuance, and upon such notice as may be required by such exchange or automated quotation system, if, after notice given by the Company to the Trustee of the proposed payment pursuant to this clause, such manner of payment will be deemed practicable by the Trustee. For the avoidance of doubt, the Trustee shall not at any time be under any duty or responsibility to any Holder to determine the Defaulted Amounts or Default Interest, or with respect to the nature, extent, or calculation of the amount of Defaulted Amounts or Default Interest owed, or with respect to the method employed in such calculation of the Defaulted Amounts or Default Interest.

Section 2.05 Execution and Authentication.

(a) In General. A Note will be valid only if executed by the Company and authenticated by the Trustee.

(b) Execution. A Note will be deemed to have been executed by the Company when an Officer of the Company signs such Note on behalf of the Company. Each Officer’s signature may be manual or facsimile, and the validity of such Officer’s signature will not depend on whether such signatory remains an Officer at the time the Trustee authenticates such Note.

(c) Authentication. A Note will be deemed authenticated when an authorized signatory of the Trustee manually signs the certificate of authentication on such Note. An authorized signatory of the Trustee will manually sign the certificate of authentication on a Note only if (i) the Company delivers such Note to the Trustee, (ii) such Note is validly executed by the Company in accordance with Section 2.05(b) hereof, and (iii) the Company delivers, before or with such Note, a Company Order setting forth (A) a request that the Trustee authenticate such Note; (B) the principal amount of such Note; (C) the name of the Holder of such Note; and (D) the date on which such Note is to be authenticated. If the Company Order also specifies that the Trustee must deliver such Note to the Holder or the Depositary, the Trustee will promptly deliver such Note in accordance with such Company Order.

 

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The Trustee may appoint an authenticating agent reasonably acceptable to the Company and at the expense of the Company. If the Trustee appoints an authenticating agent, such authenticating agent may authenticate a Note whenever the Trustee may authenticate such Note, unless limited by the terms of such appointment. Each reference in this Indenture to authentication by the Trustee will be deemed to include authentication by an authenticating agent, and an authenticating agent will have the same rights to deal with the Company as the Trustee would have if it were performing the duties that the authentication agent was validly appointed to undertake.

Section 2.06 Registrar, Paying Agent and Conversion Agent.

(a) General. The Company will maintain an office or agency in the continental United States where Notes may be presented for registration of transfer or for exchange (the “Registrar”), an office or agency where the Notes may be presented for payment, repurchase or redemption (the “Paying Agent”), an office or agency where the Notes may be presented for conversion (the “Conversion Agent”) and an office or agency where notices and demands with respect to the Notes and this Indenture may be served.

The Registrar will keep a register for the recordation of, and will record, the names and addresses of Holders, the Notes held by each Holder and the transfer, exchange, repurchase, redemption and conversion of Notes (the “Register”). Absent manifest error, the entries in the Register will be conclusive and the parties may treat each Person whose name is recorded in the Register pursuant to the terms hereof as a Holder hereunder for all purposes of this Indenture. The Register will be in written form or in any form capable of being converted into written form within a reasonably prompt period of time.

The Company may have one or more Registrars, one or more Paying Agents, one or more Conversion Agents and one or more places where notices and demands with respect to the Notes and this Indenture may be served. Before appointing any Registrar, Paying Agent or Conversion Agent that is not otherwise a party to this Indenture, the Company will enter into an appropriate agency agreement with such Registrar, Paying Agent or Conversion Agent, as the case may be, which agency agreement will implement the provisions of this Indenture that relate to such replacement or additional Registrar, Paying Agent or Conversion Agent, as the case may be. The term Registrar includes any additional registrars named pursuant to this Indenture. The term Paying Agent includes any additional paying agent named pursuant to this Indenture. The term Conversion Agent includes any additional conversion agent named pursuant to this Indenture. Upon the occurrence of any Event of Default under Section 6.01(a)(ix) or 6.01(a)(x) with respect to the Company, the Trustee shall be the Paying Agent.

(b) Initial Designations. The Company initially appoints the Trustee as each of the Registrar, the Paying Agent and the Conversion Agent, and the Notes initially may be presented for registration of transfer or for exchange, payment, repurchase, redemption and conversion to the Trustee, in its capacity as the Registrar, Paying Agent or Conversion Agent, as the case may be, at the Corporate Trust Office. Notices and demands with respect to the Notes and this Indenture may be served at the Corporate Trust Office.

 

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(c) Removal, Resignation and Replacement. The Company may remove any Registrar, Paying Agent or Conversion Agent by delivering written notice to the Trustee and to such Registrar, Paying Agent or Conversion Agent; provided, however, that no such removal will become effective unless (i) after such removal, at least one Registrar, Paying Agent and Conversion Agent will remain; (ii) a successor has accepted appointment as Registrar, Paying Agent or Conversion Agent, as the case may be, the Company and such successor have entered into an agency agreement in accordance with Section 2.06(a) hereof, and the Company has delivered written notice of such appointment and a copy of such agency agreement to the Trustee; or (iii) the Company has delivered written notice to the Trustee that the Trustee will serve as the successor Registrar, Paying Agent or Conversion Agent, as the case may be, in accordance with Section 2.06(d) hereof; and provided, further, that the right to effect any such change or removal in no way relieves the Company of its obligation to maintain a Registrar, Paying Agent and Conversion Agent in the continental United States. The Company may also change the place where notices and demands with respect to the Notes and this Indenture may be served, or reduce the number of such places; provided, however, that the right to effect any such change or reduction in no way relieves the Company of its obligation to maintain a place in the continental United States where notices and demands with respect to the Notes and this Indenture may be served.

In addition, the Registrar, Paying Agent or Conversion Agent may resign at any time by delivering written notice of such resignation to each of the Company and the Trustee; provided, however, that if the Trustee is serving as Registrar, Paying Agent or Conversion Agent, the Trustee may resign from such capacity only if it also resigns as Trustee in accordance with Section 7.07 hereof. If, after any such resignation, at least one Registrar, Paying Agent and Conversion Agent does not remain, the Trustee will immediately be deemed to serve such empty office or agency in accordance with Section 2.06(d) hereof.

(d) Failure to Maintain an Office or Agency. If the Company fails to maintain, in the continental United States, a Registrar, Paying Agent, Conversion Agent or place where notices and demands with respect to the Notes and this Indenture may be served, the Trustee will act as the Registrar, Paying Agent, Conversion Agent, or place, as the case may be, and the office where the Notes may be presented for registration of transfer or for exchange, presented for payment, repurchase or redemption or surrendered for conversion, or place where notices and demands with respect to the Notes and this Indenture may be served, as the case may be, will be the Corporate Trust Office. In each such case, the Trustee will be entitled to compensation for such action pursuant to Section 7.06 hereof.

(e) Notices. Promptly upon the effectiveness of any removal or appointment of a Registrar, Paying Agent or Conversion Agent, or upon any change in the location of the office of any Registrar, Paying Agent or Conversion Agent, or of the place where notices and demands with respect to the Notes and this Indenture may be served, the Company will deliver to each Holder written notice of such removal, appointment or change in location, as the case may be, which notice will include a brief description of the removal, appointment or change in location, as the case may be, and list the name and address of each continuing (and newly appointed, if applicable) Registrar, Paying Agent and Conversion Agent and place where notices and demands with respect to the Notes and this Indenture may be served.

 

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Section 2.07 Money Held in Trust. Except as otherwise provided herein, by no later than 10:00 a.m., New York City time, on each due date for a payment on any Note, the Company will deposit with the Paying Agent an amount of money in immediately available funds, if deposited on the due date sufficient to make such payment when due.

The Company will require that each Paying Agent (other than the Trustee, if the Trustee is a Paying Agent) agree in writing that it will (i) segregate all money it holds for making payments with respect to the Notes; (ii) hold such money in trust for the benefit of Holders; and (iii) notify the Trustee, in writing, as promptly as practicable, if the Company defaults in making any payment on the Notes.

If any such default has occurred and is continuing, the Paying Agent will, upon receiving a written request from the Trustee, forthwith pay to the Trustee all of the money it holds in trust. In addition, at any time, the Company may require a Paying Agent to pay all money that it holds for making payments with respect to the Notes to the Trustee and to account for any money it has disbursed. After delivering all of such money to the Trustee pursuant to this Section 2.07, the Paying Agent (in its capacity as such) will have no further liability for such money.

Section 2.08 Holder Lists.

The Trustee will preserve in as current a form as is reasonably practicable the most recent list available to it of the names and addresses of Holders. If the Trustee is not the Registrar, the Company will furnish to the Trustee, (i) within five Business Days after each Regular Record Date, a list of the names and addresses of Holders as of such Regular Record Date and (ii) at such other times as the Trustee may request in writing, within 30 days after receipt by the Company of such request, a list of the names and addresses of Holders as of no more than 15 days immediately prior to the date such list is furnished, in each case, in such form as the Trustee may reasonably require.

Section 2.09 Transfer and Exchange.

(a) Provisions Applicable to All Transfers and Exchanges.

(i) Subject to the restrictions set forth in this Section 2.09 and Section 11.02(f), Certificated Notes and beneficial interests in Global Notes may be transferred or exchanged from time to time as desired, and each such transfer or exchange of Certificated Notes will be noted by the Registrar in the Register.

(ii) All Notes issued upon any registration of transfer or exchange in accordance with this Indenture will be the valid obligations of the Company, evidencing the same debt, and entitled to the same benefits under this Indenture as the Notes surrendered upon such registration of transfer or exchange.

(iii) No service charge will be imposed by the Company, the Trustee or the Registrar on any Holder of a Certificated Note or any owner of a beneficial interest in a Global

 

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Note for any exchange or registration of transfer, but each of the Company, the Trustee or the Registrar may require such Holder or owner of a beneficial interest to pay a sum sufficient to cover any transfer tax, assessment or other similar governmental charge required by law or permitted by this Indenture.

(iv) None of the Company, the Trustee, the Registrar or any co-registrar will be required to exchange or register a transfer of any Note (i) surrendered for conversion, except to the extent that any portion of such Note has not been surrendered for conversion, (ii) subject to a Change of Control Repurchase Notice validly delivered pursuant to Section 3.03 hereof, except to the extent any portion of such Note is not subject to a Change of Control Repurchase Notice or the Company fails to pay the applicable Change of Control Repurchase Price when due, or (iii) after the Company has delivered a Redemption Notice pursuant to Section 12.04 hereof, except to the extent the Company fails to pay the applicable Redemption Price when due.

(v) The Trustee will have no obligation or duty to monitor, determine or inquire as to compliance with any restrictions on Transfer imposed under this Indenture or under applicable law with respect to any transfer of any interest in any Note (including any transfers between or among Depositary participants or beneficial owners of interests in any Global Note) other than to require delivery of such certificates and other documentation or evidence as are expressly required by, and to do so if and when expressly required by the terms of this Indenture, and to examine the same to determine substantial compliance as to form with the express requirements hereof.

(b) In General; Transfer and Exchange of Beneficial Interests in Global Notes. So long as the Notes are eligible for book-entry settlement with the Depositary (unless otherwise required by law and except to the extent required by Section 2.09(c) hereof):

(i) all Notes will be represented by one or more Global Notes;

(ii) every transfer and exchange of a beneficial interest in a Global Note will be effected through the Depositary in accordance with the Applicable Procedures and the provisions of this Indenture (including the restrictions on Transfer set forth in Section 2.10 hereof); and

(iii) each Global Note may be transferred only as a whole and only (A) by the Depositary to a nominee of the Depositary, (B) by a nominee of the Depositary to the Depositary or to another nominee of the Depositary, or (C) by the Depositary or any such nominee to a successor Depositary or a nominee of such successor Depositary.

(c) Transfer and Exchange of Global Notes for Certificated Notes.

(i) Notwithstanding any other provision of this Indenture, each Global Note will be exchanged for Certificated Notes if the Depositary delivers notice to the Company that:

(I) the Depositary is unwilling or unable to continue to act as Depositary; or

 

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(II) the Depositary is no longer registered as a clearing agency under the Exchange Act,

and, in each case, the Company promptly delivers a copy of such notice to the Trustee and the Company fails to appoint a successor Depositary within 90 days after receiving notice from the Depositary.

In each such case, (1) each Global Note will be deemed surrendered to the Trustee for cancellation, (2) the Trustee will promptly cancel each such Global Note in accordance with the Applicable Procedures, (3) the Company, (x) in accordance with Section 2.05 hereof, will promptly execute, for each beneficial interest in each Global Note so cancelled, an aggregate principal amount of Certificated Notes equal to the aggregate principal amount of such beneficial interest, registered in such name and authorized denominations as the Depositary specifies, and bearing such legends as such Certificated Notes are required to bear under Section 2.02 and Section 2.10 hereof, and, (y) as provided in Section 2.05(c) hereof, will promptly deliver to the Trustee such Certificated Notes and a Company Order including the information specified in Section 2.05(c) hereof with respect to such Certificated Notes, and (4) the Trustee, upon receipt of such Certificated Notes and such Company Order, in accordance with Section 2.05 hereof, will promptly authenticate, and deliver to the Holder specified in such Company Order, such Certificated Notes.

(ii) In addition:

(I) if an Event of Default has occurred and is continuing, any owner of a beneficial interest in a Global Note may exchange such beneficial interest for Certificated Notes by delivering a written request to the Company, the Registrar and the Trustee; or

(II) at any time, the Company may, in its sole discretion, at the request of the owner of a beneficial interest in a Global Note, permit the exchange of such owner’s beneficial interest for Certificated Notes, by delivering a written request to the Registrar, the Trustee and the owner of such beneficial interest.

In each case, (1) upon receipt of such request, the Registrar will promptly deliver written notice of such request to the Company and the Trustee, which notice must identify the owner of the beneficial interest to be exchanged, the aggregate principal amount of such beneficial interest and the CUSIP number of the relevant Global Note; (2) the Trustee, upon receipt of such notice, will promptly cause the aggregate principal amount of such Global Note to be reduced by the aggregate principal amount of the beneficial interest to be so exchanged in accordance with the Applicable Procedures, (3) the Company (x) in accordance with Section 2.05 hereof, will promptly execute, for such beneficial interest, a Certificated Note having aggregate principal amount equal to the aggregate principal amount of such beneficial interest, registered in the name of the owner specified in the notice delivered by the Registrar, and bearing such legends as such Certificated Note is required to bear under Sections 2.02 and 2.10 hereof, and, (y) as provided in Section 2.05(c) hereof, will promptly deliver to the Trustee such Certificated Note and a Company Order including the information specified in Section 2.05(c) hereof with respect to such Certificated Note, and (4) the Trustee, upon receipt of such Certificated Note and such Company Order, will promptly, in accordance with Section 2.05 hereof, authenticate, and deliver

 

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to the Holder specified in such Company Order, such Certificated Note. If, after such exchange, all of the beneficial interests in a Global Note have been exchanged for Certificated Notes, such Global Note will be deemed surrendered to the Trustee for cancellation, and the Trustee will cause such Global Note to be cancelled in accordance with the Applicable Procedures and the Trustee’s internal procedures.

(d) Transfer and Exchange of Certificated Notes. If Certificated Notes are issued, a Holder may:

(i) transfer a Certificated Note by: (A) surrendering such Certificated Note for registration of transfer to the Registrar, together with any endorsements or instruments of transfer reasonably required by any of the Company, the Trustee and the Registrar; (B) delivering any documentation that any of the Company, the Trustee and the Registrar require to ensure that such transfer complies with Section 2.10 hereof and any applicable securities laws, including, without limitation, the transfer and exchange form attached to such Certificated Note; and (C) satisfying any other requirements for such transfer set forth in this Section 2.09 and Section 2.10 hereof. Upon the satisfaction of conditions (A), (B) and (C), (1) the Company, (x) in accordance with Section 2.05 hereof, will promptly execute a new Certificated Note, in the name of the designated transferee, having an aggregate principal amount equal to that of the transferred Certificated Note and bearing such legends as such Certificated Note is required to bear under Sections 2.02 and 2.10 hereof, and (y) as provided in Section 2.05(c) hereof, will promptly deliver to the Trustee such Certificated Note and a Company Order including the information specified in Section 2.05(c) with respect to such Certificated Note, and (2) the Trustee, upon receipt of such Certificated Note and such Company Order, will promptly, in accordance with Section 2.05 hereof, authenticate, and deliver to the Holder specified in such Company Order, such Certificated Note;

(ii) exchange one or more Certificated Notes for one or more other Certificated Notes of any authorized denominations, and in aggregate principal amount equal to the aggregate principal amount of the one or more Certificated Notes to be exchanged, by surrendering such one or more Certificated Notes, together with any endorsements or instruments of transfer reasonably required by any of the Company, the Trustee and the Registrar, at any office or agency maintained by the Company for such purposes pursuant to Section 2.06 hereof, including, without limitation, the transfer and exchange forms attached to such Certificated Note. Whenever a Holder so surrenders one or more Certificated Notes for exchange, (1) the Company, (x) in accordance with Section 2.05 hereof, will promptly execute one or more new Certificated Notes, each in the name of such Holder, in the authorized denomination or denominations that such Holder requested (which authorized denomination or authorized denominations, as the case may be, must, in aggregate, equal the aggregate principal amount of the one or more Certificated Notes to be exchanged), and bearing a unique registration number not contemporaneously outstanding and such legends as such Certificated Note is required to bear under Sections 2.02 and 2.10 hereof, and (y) as provided in Section 2.05(c) hereof, will promptly deliver to the Trustee each such Certificated Note and a Company Order including the information specified in Section 2.05(c) with respect to each such Certificated Note, and (2) the Trustee, upon receipt of each such Certificated Note and such Company Order, will promptly, in accordance with Section 2.05 hereof, authenticate, and deliver to the Holder specified in such Company Order, each such Certificated Note; and

 

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(iii) if then permitted by the Applicable Procedures, transfer or exchange a Certificated Note for a beneficial interest in a Global Note by (A) surrendering such Certificated Note for registration of transfer or exchange, together with any endorsements or instruments of transfer reasonably required by any of the Company, the Trustee and the Registrar, at any office or agency maintained by the Company for such purposes pursuant to Section 2.06 hereof; (B) delivering any documentation that any of the Company, the Trustee and the Registrar require to ensure that such transfer complies with Section 2.10 hereof and any applicable securities laws (which may include a certification that such Note is being transferred to a “qualified institutional buyer” (as defined in Rule 144A) in accordance with Rule 144A), including, without limitation, the transfer and exchange form attached to such Certificated Note; (C) satisfying any other requirements for such transfer set forth in this Section 2.09 and Section 2.10 hereof; and (D) providing written instructions to the Trustee to make an adjustment in its books and records with respect to the applicable Global Note to reflect an increase in the aggregate principal amount of the Notes represented by such Global Note, which instructions will contain information regarding the Depositary account to be credited with such increase. Upon the satisfaction of conditions (A), (B), (C) and (D), the Trustee (1) will promptly cancel such Certificated Note and, (2) will promptly cause the aggregate principal amount of Notes represented by such Global Note to be increased by the aggregate principal amount of such Certificated Note, and credit, or cause to be credited, the account of the Person specified in the instructions provided by the exchanging Holder in an amount equal to the aggregate principal amount of such Certificated Note, in each case, in accordance with the Applicable Procedures. If at the time of such exchange, a Depositary has been appointed but no Global Notes are then outstanding, (1) the Company, (x) in accordance with Section 2.05 hereof, will promptly execute and deliver to the Trustee, a new Global Note registered in the name of the Depositary or a nominee of the Depositary, as the case may be, having the appropriate aggregate principal amount, and bearing such legends as such Global Note is required to bear under Sections 2.02 and 2.10 hereof, and (y) as provided in Section 2.05(c) hereof, will promptly deliver to the Trustee such Global Note and a Company Order including the information specified in Section 2.05(c) with respect to such Global Note, and (2) the Trustee, upon receipt of such Global Note and such Company Order, will promptly, in accordance with Section 2.05 hereof, authenticate, and deliver to the Depositary, its nominee, or a custodian of the Depositary or its nominee, as the case may be, such Global Note.

(e) Transfer and Exchange of Regulation S Global Notes for Rule 144A Global Notes.

(i) Prior to the expiration of the Restricted Period, beneficial interests in the Regulation S Global Note may be exchanged for beneficial interests in the Rule 144A Global Note only if:

(A) such exchange occurs in connection with a transfer of the Notes pursuant to Rule 144A; and

 

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(B) the transferor first delivers to the Trustee a written certificate in compliance with the terms of this Indenture to the effect that the Notes are being transferred to a Person:

(I) who the transferor reasonably believes to be a qualified institutional buyer within the meaning of Rule 144A;

(II) purchasing for its own account or the account of a qualified institutional buyer in a transaction meeting the requirements of Rule 144A; and

(III) in accordance with all applicable securities laws of the states of the United States and other jurisdictions.

(ii) Beneficial interests in a Rule 144A Global Note may be transferred to a Person who takes delivery in the form of an interest in the Regulation S Global Note, whether before or after the expiration of the Restricted Period, only if the transferor first delivers to the Trustee a written certificate in compliance with the terms of this Indenture to the effect that such transfer is being made in accordance with Rule 903 or Rule 904 of Regulation S or Rule 144 (if available) and that, if such transfer occurs prior to the expiration of the Restricted Period, the interest transferred will be held immediately thereafter through Euroclear or Clearstream.

Section 2.10 Transfer Restrictions.

(a) Notes. Each Note (and every security issued in exchange therefor or substitution thereof, except any shares of Common Stock issued upon conversion thereof, which may bear the Restricted Stock Legend) will bear the Restricted Notes Legend and will be subject to the restrictions on Transfer set forth in this Indenture (including in the Restricted Notes Legend) unless such restrictions on Transfer are eliminated or otherwise waived by written consent of the Company, and each Holder of a Note, by such Holder’s acceptance of such Note, will be deemed to be bound by the restrictions on Transfer applicable to such Note.

(b) Restricted Stock. If any shares of Common Stock are issued upon conversion of any Notes, such shares will be subject to the restrictions on transfer set forth in this Indenture (including the Restricted Stock Legend) and will bear a restricted CUSIP number unless such restrictions on transfer are eliminated or otherwise waived by written consent of the Company, and each Holder of such shares, by such Holder’s acceptance of such shares, will be deemed to be bound by the restrictions on transfer applicable to such shares. Any share of Common Stock issued upon the conversion of a Note will bear the Restricted Stock Legend unless:

(A) such shares of Common Stock are being issued to a Person (other than (x) the Company or (y) an affiliate (as defined in Rule 144) of the Company) pursuant to a registration statement that is effective under the Securities Act at the time of such issuance (including, without limitation, any registration statement effected pursuant to the Registration Rights Agreement);

(B) such shares of Common Stock are being issued to a Person (other than (x) the Company or (y) an affiliate (as defined in Rule 144) of the Company) pursuant to an available exemption from the registration requirements of the Securities Act such that, upon issuance, such shares of Common Stock will be freely transferable without restriction under the Securities Act; or

 

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(C) the Company delivers written notice to the Transfer Agent and the Registrar stating that the certificate representing such shares of Common Stock need not bear the Restricted Stock Legend to comply with applicable law.

(c) Regulation S Global Notes.

(i) Through and including the one year anniversary of the date of this Indenture (such period through and including such one year anniversary, the “Restricted Period”), beneficial interests in Global Notes that may be offered and sold in offshore transactions in reliance on Regulation S (“Regulation S Global Notes”) may be held only through Euroclear and Clearstream (as indirect participants in the Depositary), unless transferred to a Person that takes delivery through Global Notes being offered and sold to qualified institutional buyers in reliance on Rule 144A (“Rule 144A Global Notes”) in accordance with the certification requirements described in this Indenture. Beneficial interests in the Rule 144A Global Notes may not be exchanged for beneficial interests in the Regulation S Global Notes at any time except in accordance with Section 2.09(e)(ii).

(ii) Investors in the Regulation S Global Notes must initially hold their interests therein through Euroclear or Clearstream, if they are participants in such systems, or indirectly through organizations that are participants. After the expiration of the Restricted Period (but not earlier), investors may also hold interests in the Regulation S Global Notes through participants in the DTC system other than Euroclear and Clearstream.

(iii) The Depositary, Euroclear and Clearstream are under no obligation to perform or to continue to perform the procedures set forth in this Section 2.10(c), and may discontinue such procedures at any time. None of the Company, the Trustee and any of their respective agents will have any responsibility for the performance by the Depositary, Euroclear or Clearstream or their respective participants or indirect participants of their respective obligations under the rules and procedures governing their operations.

Section 2.11 Replacement Notes.

If (a)(i) a mutilated Note is surrendered to the Registrar or (ii) the Holder of a Note claims that such Note has been lost, destroyed or stolen and provides the Company and the Trustee with (A) evidence of such loss, theft or destruction that is reasonably satisfactory to the Company and the Trustee and (B) an indemnity bond or other kind of security or indemnity that the Company and the Trustee deem sufficient in their judgment to protect each of them from any loss that it may suffer upon replacement of such Note, and, in either case, (b) such Holder satisfies any other reasonable requirements of the Trustee, including the payment of any tax or other similar governmental charge required by law or permitted by this Indenture, then, unless the Company or the Trustee receives notice that such Note has been acquired by a bona fide purchaser, the Company will, in accordance with Section 2.05 hereof, promptly execute and deliver to the Trustee, and the Trustee, upon receipt of a Company Order, in accordance with Section 2.05 hereof, and the documents required by Sections 13.02 and 13.03 hereof, will promptly authenticate and deliver, in the name of such Holder, a replacement Note having the same aggregate principal amount as the Note that was mutilated or claimed to be lost, destroyed or stolen, bearing any restrictive legends required by Section 2.02 or 2.10 hereof and with a certificate number not contemporaneously outstanding.

 

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Every new Note issued pursuant to this Section 2.11 in exchange for any mutilated Note, or in lieu of any destroyed, lost or stolen Note, will constitute an original contractual obligation of the Company and any other obligor upon the Notes, regardless of whether the mutilated, destroyed, lost or stolen Note will be at any time enforceable by anyone, and will be entitled to all benefits of (and will be subject to all the limitations set forth in) this Indenture equally and proportionately with any and all other Notes duly issued hereunder.

Section 2.12 Temporary Notes. Until Certificated Notes are ready for delivery, the Company may execute and the Trustee or an authenticating agent appointed by the Trustee will, upon receipt of a Company Order, authenticate and deliver temporary Notes (printed or lithographed) (“Temporary Notes”). Temporary Notes will be issuable in any authorized denomination, and substantially in the form of Certificated Notes, but with such omissions, insertions and variations as may be appropriate for Temporary Notes, all as may be determined by the Company. Every such Temporary Note will be executed by the Company and authenticated by the Trustee or such authenticating agent upon the same conditions and in substantially the same manner, and with the same effect, as the Certificated Notes. Without unreasonable delay the Company will prepare, execute and deliver to the Trustee or such authenticating agent Certificated Notes (other than any Global Note) and thereupon any or all Temporary Notes (other than any Global Note) may be surrendered in exchange therefor, at each office or agency maintained by the Company pursuant to Section 2.06 hereof and the Trustee or such authenticating agent will authenticate and deliver in exchange for such Temporary Notes Certificated Notes having an aggregate principal amount equal to such Temporary Notes. Such exchange will be made by the Company at its own expense and without any charge therefor. Until so exchanged, the Temporary Notes will, in all respects, be entitled to the same benefits and subject to the same limitations under this Indenture as Certificated Notes authenticated and delivered hereunder.

Section 2.13 Cancellation. At any time, the Company may deliver Notes to the Trustee for cancellation. Whenever any Note is surrendered to the Registrar, Conversion Agent or Paying Agent for registration of transfer, exchange, conversion, repurchase, redemption or payment, the Registrar, Conversion Agent or Paying Agent, as the case may be, will promptly forward such Note to the Trustee. Upon receipt of any such Note, the Trustee, in its customary manner, will promptly cancel and dispose of such Note. The Company may not issue new Notes to replace Notes that the Company has repurchased, redeemed, paid or delivered to the Trustee for cancellation or that a Holder has converted pursuant to Article 11 hereof.

Section 2.14 Outstanding Notes. At any time, Notes outstanding are limited to all Notes authenticated by the Trustee except (i) those cancelled by it, (ii) those delivered to it for cancellation and (iii) those deemed not outstanding under Sections 3.05, 11.02 and 12.07 hereof and clauses (a) and (b) of this Section 2.14.

(a) If a Note is replaced pursuant to Section 2.11 hereof, such Note will cease to be outstanding at the time of its replacement unless the Trustee and the Company receive proof satisfactory to them that such Note is held by a bona fide purchaser.

 

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(b) In addition, if the Company, any other obligor or an Affiliate of the Company or an Affiliate of such other obligor holds a Note, such Note will be disregarded and deemed not to be outstanding for purposes of determining whether the Holders of the requisite aggregate principal amount of Notes have given or concurred in any request, demand, authorization, direction, notice, consent, waiver or other action hereunder, except that, solely in determining whether the Trustee shall have any liability in making a determination as to which Notes are outstanding, only Notes which a Responsible Officer actually knows to be so owned shall be disregarded. Subject to the foregoing, only Notes outstanding at the time of any such determination will be considered in such determination (including determinations pursuant to Article 6 and Article 9 hereof).

Section 2.15 Persons Deemed Owners. Prior to due presentment of a Note for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name such Note is registered in the Register as the owner of such Note for the purpose of receiving the payment of any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and accrued but unpaid interest on, such Note, for the purpose of conversion of such Note and for all other purposes whatsoever with respect to such Note, and none of the Company, the Trustee or any agent of the Company or the Trustee will be affected by any notice to the contrary.

Section 2.16 Repurchases. The Company may, from time to time, repurchase Notes in open market purchases or in negotiated transactions without delivering prior notice to Holders. Such repurchased Notes will no longer be outstanding under this Indenture.

Section 2.17 CUSIP and ISIN Numbers.

(a) Whenever “CUSIP” and “ISIN” numbers are generally in use, the Company will use CUSIP and ISIN numbers with respect to the Notes, which CUSIP and ISIN numbers will be restricted numbers. Whenever the Company uses CUSIP and ISIN numbers, the Trustee will also use CUSIP and ISIN numbers in each notice it delivers to the Holders; provided, that neither the Company nor the Trustee will be responsible for any defect in any CUSIP or ISIN number that appears on any Note, check, advice of payment or notice, including any notice delivered pursuant to Section 12.04. The Company will promptly notify the Trustee in writing in the event of any change in the CUSIP or ISIN numbers.

(b) In addition, if, when any shares of Common Stock are issued upon conversion of a Note, CUSIP and ISIN numbers are generally in use, the Company will use CUSIP and ISIN numbers with respect to such shares of Common Stock, which CUSIP and ISIN numbers (i) for shares of Common Stock to which the restrictions on Transfer set forth in the Restricted Stock Legend apply, will be restricted numbers, and (ii) for shares of Common Stock to which the restrictions on Transfer set forth in the Restricted Stock Legend do not apply, will be unrestricted numbers.

(c) Whenever any of the CUSIP or ISIN numbers with respect to the Notes or the shares of Common Stock issuable upon conversion of the Notes change, cease to be used, or begin to be used, the Company will deliver prompt written notice of such change, cessation, or beginning to each of the Trustee and the Holders.

 

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ARTICLE 3

REPURCHASE AT THE OPTION OF THE HOLDER

Section 3.01 Change of Control Permits Holders to Require the Company to Repurchase the Notes.

(a) General. If a Change of Control occurs at any time prior to the Maturity Date, each Holder will have the right to require the Company to repurchase all or any portion of its Notes on the Change of Control Repurchase Date for an amount of cash equal to the Change of Control Repurchase Price for such Notes.

(b) Change of Control Repurchase Price. The “Change of Control Repurchase Price” means, for any Notes to be repurchased on any Change of Control Repurchase Date, a price equal to the greater of:

(i) the applicable percentage of the principal amount of the Notes to be repurchased set forth in the table below (the “Applicable Premium”), plus accrued and unpaid interest to, but not including, the date of repurchase.

 

Change of Control Date

   Applicable Premium  

On or before December 31, 2014

     111

January 1, 2015 to June 30, 2015

     116

July 1, 2015 to December 31, 2015

     128

January 1, 2016 to June 30, 2016

     137

July 1, 2016 to December 31, 2016

     147

January 1, 2017 to June 30, 2017

     159

July 1, 2017 to December 31, 2017

     172

January 1, 2018 to June 30, 2018

     189

July 1, 2018 to December 31, 2018

     208

On or after January 1, 2019

     222

and

(ii) the product of (A) the aggregate principal amount of the Notes to be repurchased and (B) a fraction, the numerator of which the Company’s Equity Value on the Change of Control Date and the denominator of which is the Upside Trigger on the Change of Control Date; plus accrued and unpaid interest to, but not including, the date of repurchase.

(c) Change of Control Repurchase Date. The “Change of Control Repurchase Date” means, for any Change of Control, the date specified by the Company in the Change of Control Notice for such Change of Control, which date will be not less than 30 calendar days, nor more than 60 calendar days, immediately following the Change of Control Notice Date for such Change of Control.

 

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Section 3.02 Change of Control Notice.

(a) General. On or before the 3rd Business Day immediately following the Change of Control Date, the Company will deliver to each Holder (and to any beneficial owners of a Global Note, as required by applicable law), the Trustee and the Paying Agent written notice of such Change of Control and the resulting repurchase right (the “Change of Control Notice,” and the date of such delivery, the “Change of Control Notice Date”). Simultaneously with delivery of any Change of Control Notice to the Holders, the Trustee and the Paying Agent, the Company will publish a notice containing the same information as the Change of Control Notice in a newspaper of general circulation in The City of New York or through such other public medium as the Company may use at such time.

For any Change of Control, the Change of Control Notice corresponding to such Change of Control will specify:

(A) the events causing such Change of Control;

(B) the Change of Control Date;

(C) the last date on which a Holder may exercise its right to require the Company to repurchase its Notes as a result of such Change of Control under this Article 3;

(D) the Change of Control Repurchase Price;

(E) the Change of Control Repurchase Date;

(F) that the Change of Control Repurchase Price for any Note for which a Change of Control Repurchase Notice has been duly tendered and not validly withdrawn will be paid promptly following the later of the Change of Control Repurchase Date and the time such Note is surrendered for repurchase;

(G) the name and address of the Paying Agent, if applicable;

(H) the procedures that a Holder must follow to require the Company to repurchase a Note, including the methods of payment available for election;

(I) the procedures for withdrawing a Change of Control Repurchase Notice;

(J) that if a Note or portion of a Note is subject to a validly delivered Change of Control Repurchase Notice, unless the Company defaults in paying the Change of Control Repurchase Price for such Note or portion of a Note, interest, if any, on such Note or portion of a Note will cease to accrue on and after the Change of Control Repurchase Date; and

 

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(K) the CUSIP and ISIN number(s) of the Notes.

Notwithstanding anything to the contrary contained herein, a Change in Control Notice may be delivered in advance of a Change of Control and conditioned upon the consummation of such Change of Control, provided, that a definitive agreement is in place for the Change of Control at the time the Change of Control Notice is delivered.

(b) Failure or Defect. Notwithstanding anything provided elsewhere in this Indenture, neither the failure of the Company to deliver a Change of Control Notice nor a defect in a Change of Control Notice delivered by the Company will limit the repurchase rights of any Holder under this Article 3 or impair or otherwise affect the validity of any proceedings relating to the repurchase of any Note pursuant to this Article 3.

Section 3.03 Change of Control Repurchase Notice.

(a) General. To exercise its repurchase rights under Section 3.01(a) hereof with respect to any Notes pursuant to a Change of Control, the Holder thereof must deliver to the Paying Agent, by the Close of Business on the Business Day immediately preceding the Change of Control Repurchase Date, subject to extension to comply with applicable law:

(i) a repurchase notice containing the information set forth in Section 3.03(b) hereto (a “Change of Control Repurchase Notice”) and setting forth that such Holder is tendering such Notes for repurchase or, in the case of a Global Note, in accordance with the Applicable Procedures; and

(ii) such Notes (A) by book-entry transfer if such Notes are Global Notes, or (B) by physical delivery, if such Notes are Certificated Notes, in each case, together with any endorsements or other documents reasonably requested by the Paying Agent, the Trustee or the Company.

(b) Contents of Change of Control Repurchase Notice. The Change of Control Repurchase Notice for any Note must state:

(i) the portion of the principal amount of such Note to be repurchased;

(ii) that such Note will be repurchased by the Company pursuant to the applicable provisions of the Notes and the provisions of this Article 3 hereof;

(iii) if such Note is a Certificated Note, the certificate number of such Note; and

(iv) the method of payment by which such Holder elects to be paid and, if applicable, wire transfer instructions on which the Trustee and Paying Agent may conclusively rely to make the payment of the Change of Control Repurchase Price.

If the Notes to be repurchased are Global Notes, the Change of Control Repurchase Notice for such Notes must comply with the Applicable Procedures.

 

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(c) Notice to the Company. If any Holder validly delivers to the Paying Agent a Change of Control Repurchase Notice with respect to a Note or any portion of a Note, the Paying Agent will promptly deliver to the Company a copy of such Change of Control Repurchase Notice.

(d) Effect of Improper Notice. Unless and until the Paying Agent receives a validly endorsed and delivered Change of Control Repurchase Notice with respect to a Note, together with such Note, in a form that conforms in all material aspects with the description contained in such Change of Control Repurchase Notice, the Holder submitting the Notes will not be entitled to receive the Change of Control Repurchase Price for such Note.

Section 3.04 Withdrawal of Change of Control Repurchase Notice.

(a) General. After a Holder delivers a Change of Control Repurchase Notice with respect to a Note, such Holder may withdraw such Change of Control Repurchase Notice with respect to such Note or any portion of such Note by delivering to the Paying Agent a written notice of withdrawal prior to the Close of Business on the Business Day immediately preceding the Change of Control Repurchase Date. Any such withdrawal notice must state:

(A) the principal amount of the Notes with respect to which such notice of withdrawal pertains;

(B) the principal amount, if any, of the Notes that remains subject to the original Change of Control Repurchase Notice; and

(C) if the Notes subject to such Change of Control Repurchase Notice were Certificated Notes, the certificate numbers of the Notes to be withdrawn and the Notes that will remain subject to the Change of Control Repurchase Notice.

If the Notes to be withdrawn are Global Notes, a Holder must deliver its notice of withdrawal in compliance with the Applicable Procedures.

(b) Return of Note. Upon receipt of a validly delivered withdrawal notice, the Paying Agent will promptly (i) if such notice pertains to a Certificated Note or a portion of a Certificated Note, return such Note or portion of a Note to such Holder, in the amount specified in such withdrawal notice; and (ii) if such notice pertains to a beneficial interest in a Global Note, in compliance with the Applicable Procedures, deem to be cancelled any instructions for book-entry transfer of such beneficial interest, in the amount specified in such withdrawal notice.

(c) Notice to the Company. If any Holder validly delivers to the Paying Agent a notice of withdrawal with respect to a Note or any portion of a Note, the Paying Agent will promptly deliver to the Company a copy of such notice of withdrawal.

Section 3.05 Effect of Change of Control Repurchase Notice.

(a) General. If a Holder validly delivers to the Paying Agent a Change of Control Repurchase Notice (together with all necessary endorsements) with respect to a Note, such Holder may no longer convert such Note unless and until such Holder validly withdraws such Change of Control Repurchase Notice in accordance with Section 3.04 hereof.

 

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(b) Timing of Payment. Upon the Paying Agent’s receipt of (i) a valid Change of Control Repurchase Notice (together with all necessary endorsements) and (ii) the Notes to which such Change of Control Repurchase Notice pertains, the Holder of the Notes to which such Change of Control Repurchase Notice pertains will be entitled, except to the extent such Holder has validly withdrawn such Change of Control Repurchase Notice in accordance with Section 3.04 hereof, to receive, and the Paying Agent will promptly mail or wire transfer to each such Holder, the Change of Control Repurchase Price with respect to such Notes on the later of the following dates (subject to extension to comply with applicable law): (i) the Change of Control Repurchase Date and (ii) (A) if such Notes are Certificated Notes, the date of delivery of the certificate representing such Notes to the Paying Agent, duly endorsed, or (B) if such Notes are Global Notes, the date of book-entry transfer or delivery of such Notes to the Paying Agent, or, if such later date is not a Business Day, the Business Day immediately following such later date.

(c) Effect of Deposit. If, as of 10:00 a.m., New York City time, on the Change of Control Repurchase Date for any Change of Control, the Company, in accordance with Section 3.08 hereof, has deposited with the Paying Agent money sufficient to pay the Change of Control Repurchase Price for every Note subject to a Change of Control Repurchase Notice validly delivered in accordance with Section 3.03 hereof and not validly withdrawn in accordance with Section 3.04 hereof, at the Close of Business on the Change of Control Repurchase Date:

(A) the Notes to be repurchased will cease to be outstanding and interest (except Default Interest) will cease to accrue on such Notes (whether or not book-entry transfer of such Notes is made or whether or not such Notes are delivered to the Paying Agent); and

(B) all other rights of the Holders of such Notes with respect to such Notes will terminate (other than the right to receive payment of the Change of Control Repurchase Price upon delivery or transfer of such Notes and any Defaulted Amounts or Default Interest with respect to the Notes).

Section 3.06 Notes Repurchased in Part. If any Certificated Note is to be repurchased only in part, the Holder must surrender such Note at the office of the Paying Agent (with, if the Company or the Trustee so requires, due endorsement by, or a written instrument of transfer in form satisfactory to the Company and the Trustee duly executed by, the Holder of such Note or such Holder’s attorney-in-fact, duly authorized in writing), whereupon the Company, in accordance with Section 2.05 hereof, will promptly execute, and, upon receipt of a Company Order and the documents required by Sections 13.02 and 13.03 hereof, the Trustee, in accordance with Section 2.05 hereof, will promptly authenticate and deliver, to the surrendering Holder, a new Note or Notes of any authorized denomination or denominations requested by such Holder in aggregate principal amount equal to the portion of the principal amount of the Note so surrendered which is not repurchased. If any Global Note is repurchased in part, the Company will instruct the Trustee to decrease the principal amount of such Global Note by the principal amount repurchased.

 

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Section 3.07 Covenant to Comply With Securities Laws Upon Repurchase of Notes. In connection with any repurchase offer pursuant to a Change of Control Repurchase Notice under this Article 3, the Company will, to the extent applicable, (i) comply with any tender offer rules under the Exchange Act (including Rule 14e-1 thereunder) that may be applicable at the time of the offer to repurchase the Notes and (ii) otherwise comply with any applicable United States federal and state securities laws so as to permit Holders to exercise their rights and obligations under Section 3.01 hereof in the time and in the manner specified in Sections 3.01 and 3.03 hereof. To the extent that the provisions of any securities laws or regulations conflict with the provisions of this Article 3, the Company will comply with the applicable securities laws and regulations and will not be deemed to have breached its obligations under the provisions of this Article 3 by virtue of such compliance.

Section 3.08 Deposit of Change of Control Repurchase Price. Prior to 10:00 a.m., New York City time, on the Change of Control Repurchase Date, the Company will (i) deposit with the Trustee or with the Paying Agent (or, if the Company or any of the Subsidiaries is acting as the Paying Agent, will segregate and hold in trust as provided in Section 2.07 hereof) an amount of immediately available funds sufficient to pay the Change of Control Repurchase Price of all the Notes or portions thereof that the Company is required to repurchase on such Change of Control Repurchase Date and (ii) deliver to the Trustee an Officers’ Certificate stating the aggregate principal amount of Notes or portions of Notes being repurchased by the Company.

Section 3.09 Covenant Not to Repurchase Notes Upon Certain Events of Default.

(a) General. Notwithstanding anything to the contrary in this Article 3, the Company will not repurchase and will not be obligated to repurchase any Notes under this Article 3 if, as of the Change of Control Repurchase Date, the principal amount of the Notes has been accelerated, such acceleration has not been rescinded and such acceleration did not result from a Default that would be cured by the Company’s payment of the Change of Control Repurchase Price.

(b) Deemed Withdrawals. If, on any Change of Control Repurchase Date, (i) a Change of Control Repurchase Notice for a Note has been validly tendered in accordance with Section 3.03 hereof and has not been validly withdrawn in accordance with Section 3.04 hereof, and (ii) pursuant to this Section 3.09, the Company is not permitted to repurchase Notes, the Paying Agent, upon receipt of written notice from the Company stating that the Company, pursuant to this Section 3.09, is not permitted to repurchase Notes, will deem such Change of Control Repurchase Notice to be withdrawn.

(c) Return of Notes. If a Holder tenders a Note for purchase pursuant to this Article 3 and, on the Change of Control Repurchase Date, pursuant to this Section 3.09, the Company is not permitted to repurchase such Note, the Paying Agent will (i) if such Note is a Certificated Note, return such Note to such Holder, and (ii) if such Note is held in book-entry form, in compliance with the Applicable Procedures, deem to be cancelled any instructions for book-entry transfer of such Note.

 

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ARTICLE 4

COVENANTS

Section 4.01 Payment of Notes. The Company will pay or cause to be paid the principal or Terminal Value of, any Change of Control Repurchase Price or Redemption Price for, any accrued and unpaid interest on, the Notes on the dates and in the manner required under this Indenture. Any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, or accrued but unpaid interest in respect of a conversion of, a Note will be considered paid on the date due if the Paying Agent, if other than the Company or any of the Subsidiaries, holds, as of 10:00 a.m. New York City time on the due date, money deposited by the Company in immediately available funds and designated for, and sufficient to pay, such principal, Terminal Value, Change of Control Repurchase Price, Redemption Price, interest or cash then due. To the extent lawful, the Company will also pay Default Interest on any Defaulted Amounts in accordance with Section 2.04 hereof.

Section 4.02 144A Information. Whenever the Company is not subject to Section 13 or Section 15(d) of the Exchange Act, the Company will, upon the request of a Holder or beneficial owner of the Notes, promptly furnish or cause to be furnished to the applicable Holder, beneficial owner, or any prospective purchaser designated by the applicable Holder or beneficial owner, of the Notes, all of the information that a prospective purchaser of the Notes is required to receive under Rule 144A(d)(4) of the Securities Act for the Notes to be resold to such prospective purchaser pursuant the exemption from registration provided by Rule 144A.

Section 4.03 Reports.

(a) So long as any Notes are outstanding, the Company will furnish to the Holders and the Trustee within 60 days following the end of each of the Company’s first three fiscal quarters and within 120 days following the end of each fiscal year, customary quarterly and annual financial statements (including all appropriate notes relating thereto), together with a Management’s Discussion and Analysis of Financial Condition and Results of Operations (the “Reports”).

All such financial statements will be prepared in all material respects in accordance with GAAP and will include a reasonably detailed presentation, either on the face of the financial statements or in the footnotes thereto, and in Management’s Discussion and Analysis of Financial Condition and Results of Operations, of the financial condition and results of operations of the Company and the Subsidiaries. In addition, the annual financial statements will include an audit report thereon by the Company’s certified independent accountants.

The Company will furnish the Reports by posting such Reports on a website no later than the date the Company is required to furnish those Reports to the Trustee and the Holders and maintain such posting until the earlier of the closing of a Qualified PO or the last date on which any Notes remain outstanding. Access to such information and Reports on such website may be subject to a confidentiality acknowledgment and may be password-protected; provided, however, that the Trustee shall have no obligation whatsoever to determine whether or not such information, documents or reports have been so filed or posted.

 

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The Company also will arrange and participate in quarterly conference calls to discuss its results of operations with the Holders, no later than 15 days following the date on which the Reports are made available as provided above. Dial-in conference call information will be included in or provided together with such Reports and may be password-protected.

(b) Notwithstanding the foregoing, (i) the Company may satisfy its obligation to furnish the Reports pursuant to this Section 4.03 by filing the same for public availability with the SEC; provided, however, that the Trustee shall have no obligation whatsoever to determine whether or not such Reports have been so filed, (ii) no certifications or attestations concerning the financial statements or disclosure controls and procedures or internal controls that would otherwise be required pursuant to the Sarbanes-Oxley Act of 2002 will be required, (iii) nothing contained in this Indenture shall otherwise require the Company to comply with the terms of the Sarbanes-Oxley Act of 2002 at any time when it would not otherwise be subject to such statute and (iv) the foregoing requirements will not apply so long as the issuer of the Common Stock is subject to the reporting requirements of Section 13 or 15(d) of the Exchange Act.

(c) Any and all Defaults or Events of Default arising from a failure to furnish or file in a timely manner a Report required by this covenant shall be deemed cured (and the Company shall be deemed to be in compliance with this Section 4.03) upon furnishing or filing such Report as contemplated by this Section 4.03 (but without regard to the date on which such Report is so furnished or filed); provided that such cure shall not otherwise affect the rights of the Holders under Section 6.01 hereto if any principal or Terminal Value of, Change of Control Repurchase Price for, and accrued but unpaid interest on the Notes have been accelerated in accordance with Section 6.02 hereto and such acceleration has not been rescinded or cancelled prior to such cure.

(d) The Company and the Trustee agree that furnishing of the Reports to the Trustee is for informational purposes only and the Trustee’s receipt of such Reports shall not constitute constructive notice of any information contained therein or determinable from information contained therein, including the Company’s compliance with this Article 4 (as to which the Trustee is entitled to rely exclusively on Officers’ Certificates). The Trustee shall have no obligation whatsoever to determine whether or not the Reports have been filed or posted pursuant to this Section 4.03.

Section 4.04 Compliance Certificate.

(a) Annual Compliance Certificate. Within 120 days after the end of each fiscal year of the Company, beginning with the fiscal year ending on December 31, 2014, the Company will deliver to the Trustee an Officers’ Certificate, which Officers’ Certificate will state (i) that the Officers signing such Officers’ Certificate have supervised a review of the activities of the Company and the Subsidiaries with a view to determining whether the Company has kept, observed, performed and fulfilled its obligations under this Indenture during the preceding fiscal year, and (ii) to the knowledge of each of the Officers signing such Officers’ Certificate, (A) whether the Company has kept, observed, performed and fulfilled each and every covenant contained in this Indenture and are not in default in the performance or observance of any of the terms, provisions and conditions of this Indenture (without regard to any period of grace or

 

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requirement of notice provided under this Indenture) or, if one or more Defaults or Events of Default have occurred, a description, in reasonable detail, of what events triggered such Defaults or Events of Default and what actions the Company is taking or proposes to take with respect to such Defaults or Events of Default, and (B) whether any event has occurred and remains in existence by reason of which any payment of principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and accrued but unpaid interest on a Note is prohibited, and, if any such event has occurred and remains in existence, a description, in reasonable detail, of such event or events and what actions the Company is taking or proposes to take with respect to such event or events.

(b) Certificate of Default. Within 30 days after an Officer of the Company becomes aware that a Default has occurred, the Company will deliver to the Trustee an Officers’ Certificate describing such Default, its status and a description, in reasonable detail, of what action the Company is taking or propose to take with respect to such Default.

Section 4.05 Limitation on Indebtedness.

(a) The Company will not, and will not permit any of the Subsidiaries to, directly or indirectly, create, incur, issue, assume, Guarantee or otherwise become directly or indirectly liable, contingently or otherwise, with respect to (collectively, “incur”) any Indebtedness (including Acquired Debt), except for the following items of Indebtedness (collectively, “Permitted Indebtedness”):

(i) Indebtedness under Credit Facilities, including the Term Loan; provided that the aggregate principal amount of all Indebtedness outstanding at any time under this clause (i) under all Credit Facilities after giving effect to such incurrence does not exceed $1,075,000,000;

(ii) Existing Indebtedness;

(iii) Indebtedness represented by the Notes issued on the Issue Date and any Guarantees thereof;

(iv) the incurrence by the Company or any of the Subsidiaries of Indebtedness represented by Capital Lease Obligations, mortgage financings, industrial revenue bonds, purchase money obligations or other Indebtedness, or synthetic lease obligations, in each case, incurred for the purpose of financing all or any part of the purchase price or cost of design, development, construction, installation or improvement of property (real or personal and including Capital Stock), plant or equipment used in the business of the Company or any of the Subsidiaries (in each case, whether through the direct purchase of such assets or the Equity Interests of any Person owning such assets), in an aggregate principal amount, taken together with Permitted Refinancing Indebtedness in respect thereof, not to exceed $25,000,000 at any time outstanding;

(v) the incurrence by the Company or any of the Subsidiaries of Permitted Refinancing Indebtedness in exchange for, or the net cash proceeds of which are used to refund, refinance or replace, Indebtedness (other than intercompany Indebtedness) that was permitted by the Indenture to be incurred under clause (ii), (iii) or (iv) or this clause (v) of this paragraph;

 

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(vi) the incurrence by the Company or any of the Subsidiaries of intercompany Indebtedness between or among the Company and any of the Subsidiaries; provided, however, that:

(A) (I) if the Company is the obligor on such Indebtedness and a Guarantor is not the obligee, such Indebtedness must be expressly subordinated to the prior payment in full in cash of all obligations with respect to the Notes, and (II) if any Guarantor is the obligor of such Indebtedness and neither the Company nor another Guarantor is the obligee, such Indebtedness must be expressly subordinated to the prior payment in full in cash of all obligations of such Guarantor with respect to its Guarantee of the Notes; and

(B) (I) any subsequent issuance or transfer of Equity Interests that results in any such Indebtedness being held by a Person other than the Company or any Subsidiary and (II) any sale or other transfer of any such Indebtedness to a Person that is not either the Company or a Subsidiary, shall be deemed, in each case, to constitute an incurrence of such Indebtedness by the Company or such Subsidiary, as the case may be, that was not permitted by this clause;

(vii) in-kind obligations relating to net oil and natural gas balancing positions arising in the ordinary course of business;

(viii) the accrual of interest, accretion or amortization of original issue discount, the payment of interest on any Indebtedness in the form of additional Indebtedness with the same terms, and the payment of dividends on Disqualified Stock, in the form of additional shares of the same class of Disqualified Stock;

(ix) any obligations in respect of plugging and abandonment bonds, reimbursement bonds, completion bonds, performance bonds, bid bonds, appeal bonds, surety bonds, bankers acceptances, letters of credit, insurance obligations or bonds and other similar bonds and obligations incurred by the Company or any Subsidiary in the ordinary course of business and any Guarantees or letters of credit functioning as or supporting any of the foregoing bonds or obligations;

(x) any obligation (including deferred premiums) under Interest Rate Agreements, Currency Agreements and Commodity Agreements; provided, that such Interest Rate Agreements, Currency Agreements and Commodity Agreements are related to business transactions of the Company or the Subsidiaries and are entered into for bona fide hedging purposes of the Company or the Subsidiaries (as determined in good faith by the Board of Directors or senior management of the Company);

(xi) any obligation arising from agreements of the Company or a Subsidiary providing for indemnification, Guarantee, adjustment of purchase price, holdback, contingency payment obligation based on the performance of the acquired or disposed asset or similar obligations, in each case, incurred or assumed in connection with the acquisition or disposition of any business, asset or Capital Stock of a Subsidiary;

(xii) any obligation arising from the honoring by a bank or other financial institution of a check, draft or similar instrument drawn against insufficient funds in the ordinary course of business, provided, however, that such Indebtedness is extinguished within five Business Days of incurrence;

 

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(xiii) Indebtedness in the form of a Guarantee by the Company or any Subsidiary of any obligation (whether payment, performance or otherwise) of the Company or any other Subsidiary so long as such obligation is otherwise permitted under the Indenture;

(xiv) endorsements of negotiable instruments for collection in the ordinary course of business;

(xv) Indebtedness owing in connection with the financing of insurance premiums in the ordinary course of business; and

(xvi) additional Indebtedness in an aggregate principal amount at any time outstanding not to exceed $25,000,000.

(b) For purposes of determining compliance with this Section 4.05:

(i) in the event that an item of proposed Indebtedness meets the criteria of more than one of the categories of Permitted Indebtedness described in clauses (i) through (xvi) above, the Company will be permitted to classify such item of Indebtedness (or any portion thereof) on the date of its incurrence, subject to clause (ii) below, and may later reclassify such items of Indebtedness (or any portion thereof), in any manner that complies with this covenant, and only be required to include the amount and type of such Indebtedness in one of such clauses or may include the amount and type of such Indebtedness partially in one such clause and partially in one or more other such clauses;

(ii) all Indebtedness outstanding on the date of this Indenture under the Term Loan shall be deemed initially incurred on the Issue Date under clause (i) of the definition of Permitted Indebtedness and not clause (ii) of the definition of Permitted Indebtedness;

(iii) Guarantees of, or obligations in respect of letters of credit relating to, Indebtedness which is otherwise included in the determination of a particular amount of Indebtedness shall not be included;

(iv) if obligations in respect of letters of credit are incurred pursuant to a Credit Facility and are being treated as incurred pursuant to clause (1) of the definition of Permitted Indebtedness and the letters of credit relate to other Indebtedness, then such other Indebtedness shall not be included;

(v) the amount of Indebtedness issued at a price that is less than the principal amount thereof will be equal to the amount of the liability in respect thereof determined in accordance with GAAP;

(vi) Indebtedness of any Person existing at the time such Person becomes a Subsidiary shall be deemed to have been incurred by the Company and the Subsidiary at the time such Person becomes a Subsidiary; and

 

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(vii) the accrual of interest or dividends, the accretion or amortization of original issue discount, the payment of interest on any Indebtedness in the form of additional Indebtedness with the same terms, the reclassification of preferred equity as Indebtedness due to a change in accounting principles, the payment of dividends on Disqualified Stock or preferred equity in the form of additional shares of the same class of Disqualified Stock or preferred equity will not be deemed to be an incurrence of Indebtedness or an issuance of Disqualified Stock or preferred equity for purposes of this Section 4.05.

(c) For purposes of determining compliance with any U.S. dollar-denominated restriction on the incurrence of Indebtedness, the U.S. dollar-equivalent principal amount of Indebtedness denominated in a foreign currency shall be calculated based on the relevant currency exchange rate in effect on the date such Indebtedness was incurred, in the case of term Indebtedness, or first committed, in the case of revolving credit Indebtedness; provided that if such Indebtedness is incurred to refinance other Indebtedness denominated in a foreign currency, and such refinancing would cause the applicable U.S. dollar-dominated restriction to be exceeded if calculated at the relevant currency exchange rate in effect on the date of such refinancing, such U.S. dollar-dominated restriction shall be deemed not to have been exceeded so long as the principal amount of such refinancing Indebtedness does not exceed the principal amount of such Indebtedness being refinanced. Notwithstanding any other provision of this covenant, the maximum amount of Indebtedness that the Company may incur pursuant to this covenant shall not be deemed to be exceeded solely as a result of fluctuations in the exchange rate of currencies. The principal amount of any Permitted Refinancing Indebtedness, if incurred in a different currency from the Indebtedness being refinanced, shall be calculated based on the currency exchange rate applicable to the currencies in which such Permitted Refinancing Indebtedness is denominated that is in effect on the date of such refinancing.

Section 4.06 Taxes. The Company will pay, and will cause each of the Subsidiaries to pay, prior to delinquency, all material taxes, assessments and governmental levies except such as are contested in good faith and by appropriate proceedings or where the failure to effect such payment is not adverse in any material respect to the Holders.

Section 4.07 Corporate Existence. Subject to Article 5 hereof, the Company will do or cause to be done all things necessary to preserve and keep in full force and effect its corporate existence in accordance with its organizational documents (as the same may be amended from time to time).

Section 4.08 Stay, Extension and Usury Laws. The Company covenants that, to the extent that it may lawfully do so, it will not at any time insist upon, plead, or in any manner whatsoever claim or take the benefit or advantage of, any stay, extension or usury law wherever enacted, now or at any time hereafter in force, that may affect the covenants or the performance of this Indenture; and the Company, to the extent that it may lawfully do so, hereby expressly waives all benefit or advantage of any such law, and covenants that it will not, by resort to any such law, hinder, delay or impede the execution of any power herein granted to the Trustee, but will instead suffer and permit the execution of every such power as though no such law has been enacted.

 

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Section 4.09 Further Instruments and Acts. Upon request of the Trustee, the Company will execute and deliver such further instruments and do such further acts as may be reasonably necessary or proper to carry out more effectively the terms of this Indenture.

Section 4.10 Determination of Equity Value. Whenever the calculation of the Equity Value of the Company is required as of a specified date, the Company will cause a determination of such Equity Value to be made by three investment banking firms or valuation firms of national reputation (which may include the initial purchasers in the offering of the Notes or the banks acting as underwriters, initial purchasers, agents or advisors in the transaction triggering the determination) engaged by the Company at its expense. In the event that such firms do not or cannot agree on such Equity Value for the Company, the Equity Value for the Company shall be equal to the average of the three Equity Values for the Company determined by such firms. Any such determination will be final and binding on the Holders.

Section 4.11 Issuance of Conversion Shares . In connection with the consummation of a Qualified PO, the Company shall amend its certificate of incorporation to authorize the maximum number of Conversion Shares issuable upon conversion of the Notes, such Conversion Shares shall be duly and validly authorized and reserved for issuance upon conversion of the Notes, and the Company shall take such other action as will be necessary to comply with the Company’s obligations set forth in Article XI.

ARTICLE 5

CONSOLIDATION, MERGER AND SALE OF ASSETS

Section 5.01 Company May Consolidate, Merge or Sell Its Assets Only on Certain Terms. The Company will not, directly or indirectly, (1) consolidate with or merge with or into, or (2) sell, convey, transfer or lease all or substantially all of its properties and assets to, any other Person (any such transaction, a “Reorganization Event”), unless:

(a) either:

(i) the Company is the surviving Person; or

(ii) the resulting, surviving or transferee Person (if other than the Company) of such Reorganization Event (the “Reorganization Successor Corporation”):

(A) is a business entity organized and validly existing under the laws of the United States of America, any State thereof or the District of Columbia; and

(B) expressly assumes, by executing and delivering a supplemental indenture to the Trustee that is reasonably satisfactory in form to the Trustee in accordance with Section 9.03 hereof, all of the obligations of the Company under the Notes and this Indenture;

(b) immediately after giving effect to such Reorganization Event, no Default will have occurred and be continuing; and

 

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(c) prior to the effective date of such Reorganization Event, the Company delivers to the Trustee an Officers’ Certificate and an Opinion of Counsel, each stating that:

(i) such Reorganization Event and such supplemental indenture comply with Section 5.01(a) hereof; and

(ii) all conditions precedent to such Reorganization Event provided in this Indenture have been satisfied.

Section 5.02 Successor Substituted. If any Reorganization Event occurs that complies with Sections 5.01(a)(ii) and 5.01(b) hereof, and the Company has complied with Section 5.01(c) hereof:

(a) from and after the date of such Reorganization Event, the Reorganization Successor Corporation for such Reorganization Event will succeed to, and be substituted for, and may exercise every right and power of, the Company under this Indenture with the same effect as if such Reorganization Successor Corporation had been named as the Company herein; and

(b) except in the case of a Reorganization Event that is a conveyance, transfer or lease of all or substantially all of the Company’s assets, the Person named as the “Company” in the first paragraph of this Indenture or any successor (other than such Reorganization Successor Corporation) that will thereafter have become such in the manner prescribed in this Article 5 will be released from its obligations under this Indenture and may be dissolved, wound up and liquidated at any time.

ARTICLE 6

DEFAULTS AND REMEDIES

Section 6.01 Events of Default.

(a) General. Each of the following events will be an “Event of Default”:

(i) the Company fails to pay any principal or Terminal Value of, or Change of Control Repurchase Price or Redemption Price for, the Notes when due at maturity, upon repurchase upon a Change of Control, redemption, declaration of acceleration or otherwise, whether or not prohibited by Article 10 hereof;

(ii) the Company fails to pay any interest when due and such failure continues for a period of 30 days after the applicable due date, whether or not prohibited by Article 10 hereof;

(iii) the Company fails to give any Change of Control Notice when due;

(iv) the Company fails to comply with its obligation to convert a Note in accordance with Article 11 hereof upon a Holder’s exercise of its conversion rights with respect to such Note;

(v) the Company fails to comply with its obligations under Article 5 hereof;

 

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(vi) the Company fails to perform or observe any of its covenants or warranties in this Indenture or in the Notes (other than a covenant or agreement specifically addressed in clauses (i) through (v) above) and such failure continues for a period of 30 days after (A) the Company receives written notice of such failure from the Trustee or (B) the Company and the Trustee receive notice of such failure from Holders of at least 25% of the aggregate principal amount of then outstanding Notes;

(vii) the default by the Company or any of the Subsidiaries with respect to any mortgage, agreement or other instrument under which there may be outstanding, or by which there may be secured or evidenced, any indebtedness for money borrowed by the Company and/or any of the Subsidiaries in excess of $35,000,000 in the aggregate, whether such indebtedness exists as of the Issue Date or is later created, if that default:

(A) results in such indebtedness becoming or being declared due and payable (prior to its express maturity); or

(B) constitutes a failure to pay the principal of, or interest on, such indebtedness when due and payable at its stated maturity, upon required repurchase, upon declaration or otherwise, subject in the case of interest to any applicable grace periods;

(viii) a final judgment for the payment of $35,000,000 or more (excluding any amounts covered by insurance) is rendered against the Company or any of the Subsidiaries, and such judgment is not discharged or stayed within 60 days after (i) the date on which all rights to appeal such judgment have expired if no appeal has commenced, or (ii) the date on which all rights to appeal have been extinguished;

(ix) the Company or any Significant Subsidiary or group of Subsidiaries of the Company that together would constitute a “significant subsidiary” (as defined in Rule 1-02(w)), pursuant to or within the meaning of any Bankruptcy Law:

(A) commences a voluntary case seeking liquidation, reorganization or other relief with respect to it;

(B) consents to the entry of an order for relief against it in an involuntary case;

(C) consents to the appointment of a Custodian of it or for any substantial part of its property;

(D) makes a general assignment for the benefit of its creditors; or

(E) generally is not paying its debts as they become due,

but excluding any of the above for the purposes of a solvent reconstruction, amalgamation or winding-up in connection with a transfer of assets solely to the Company or a scheme of arrangement made in compliance with Article 5 hereof that does not result in the liquidation, provisional liquidation, winding-up or dissolution of the Company or any Significant Subsidiary; or

 

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(x) a court of competent jurisdiction enters an order or decree under any Bankruptcy Law that:

(A) is for relief against the Company or any Significant Subsidiary in an involuntary case or proceeding;

(B) appoints a Custodian of the Company or any Significant Subsidiary, or for any substantial part of the property of the Company or any Significant Subsidiary;

(C) orders the winding up or liquidation of the Company or any Significant Subsidiary; or

(D) grants any similar relief under any foreign laws;

and, in each such case, the order or decree remains undismissed and unstayed and in effect for 60 days, but excluding any of the above for the purposes of a solvent reconstruction, amalgamation or winding-up in connection with a transfer of assets solely to the Company or a scheme of arrangement made in compliance with Article 5 hereof that does not result in the liquidation, provisional liquidation, winding-up or dissolution of the Company or any Significant Subsidiary.

(b) Cause Irrelevant. Each of the events enumerated in Section 6.01(a) hereof will constitute an Event of Default whatever the cause and regardless of whether voluntary or involuntary or effected by operation of law or pursuant to any judgment, decree or order of any court or any order, rule or regulation of any administrative or governmental body.

Section 6.02 Acceleration.

(a) Automatic Acceleration in Certain Circumstances. If an Event of Default specified in Section 6.01(a)(ix) or 6.01(a)(x) hereof occurs, an amount equal to the applicable Terminal Value on the date of such Event of Default on the then outstanding Notes will immediately become due and payable without any further action or notice by any party.

(b) Optional Acceleration. If any Event of Default (other than an Event of Default specified in Sections 6.01(a)(ix) or 6.01(a)(x)) occurs and is continuing, the Trustee, by delivering a written notice to the Company, or the Holders of at least 25% in aggregate principal amount of the Notes then outstanding, by delivering a written notice to the Company and the Trustee, may declare the applicable Terminal Value of all then outstanding Notes immediately due and payable, and upon such declaration, the applicable Terminal Value of all then outstanding Notes will immediately become due and payable in cash.

(c) Rescission of Acceleration. Notwithstanding anything to the contrary in this Indenture, the Holders of a majority of the aggregate principal amount of the then outstanding

 

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Notes may, on behalf of the Holders of all of the then outstanding Notes, rescind any acceleration of the Notes and its consequences hereunder by delivering written notice to the Trustee if (i) such rescission would not conflict with any judgment or decree of a court of competent jurisdiction and (ii) all existing Events of Default (other than the nonpayment of any principal or Terminal Value of, Change of Control Repurchase Price or the Redemption Price for, or interest on the Notes that has become due solely as a result of acceleration) have been cured or waived. No such rescission will affect any subsequent Default or impair any right consequent thereto.

Section 6.03 Other Remedies. If an Event of Default occurs and is continuing, the Trustee may pursue any available remedy to collect the payment of any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, or accrued and unpaid interest on the Notes or to enforce the performance of any provision of the Notes or this Indenture regarding any other matter.

The Trustee may maintain a proceeding even if it does not possess any of the Notes or does not produce any of the Notes in the proceeding. A delay or omission by the Trustee or any Holder in exercising any right or remedy accruing upon an Event of Default will not impair the right or remedy or constitute a waiver of or acquiescence in the Event of Default. No remedy is exclusive of any other remedy. All available remedies are cumulative.

Section 6.04 Waiver of Past Defaults. If an Event of Default described in Sections 6.01(a)(i), 6.01(a)(ii), 6.01(a)(iii), Section 6.01(a)(iv) or 6.01(a)(vi) (which, in the case of Section 6.01(a)(vi) only, relates to a covenant that cannot be amended without the consent of each affected Holder) or a Default that would lead to such an Event of Default occurs and is continuing, such Event of Default or Default may be waived only with the consent of each affected Holder. Every other Event of Default or Default may be waived by the Holders of a majority of the aggregate principal amount of then outstanding Notes. Whenever any Event of Default is so waived, it will cease to exist, and whenever any Default is so waived, it will be deemed cured and any Event of Default arising therefrom will be deemed not to occur. However, no such waiver will extend to any subsequent or other Default or Event of Default or impair any consequent right.

Section 6.05 Control by Majority. At any time, the Holders of a majority of the aggregate principal amount of then outstanding Notes may direct the time, method and place of conducting any proceeding for any remedy available to the Trustee or for exercising any trust or power conferred on the Trustee. However, the Trustee may refuse to follow any direction that conflicts with law or this Indenture or, subject to Section 7.01 hereof, that the Trustee determines to be unduly prejudicial to the rights of a Holder or to the Trustee, or that would potentially involve the Trustee in personal liability unless the Trustee is offered indemnity or security satisfactory to it against any loss, liability or expense to the Trustee that may result from the Trustee’s instituting such proceeding as the Trustee. Prior to taking any action hereunder, the Trustee will be entitled to indemnification or security satisfactory to it against all losses, liabilities and expenses caused by taking or not taking such action.

 

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Section 6.06 Limitation on Suits. Except in the case of an Event of Default described in Section 6.01(a)(i), 6.01(a)(ii), 6.01(a)(iii) or Section 6.01(a)(iv) hereof, no Holder may pursue a remedy with respect to this Indenture or the Notes unless:

(a) such Holder has previously delivered to the Trustee written notice that an Event of Default has occurred and is continuing;

(b) the Holders of at least 25% of the aggregate principal amount of then-outstanding Notes deliver to the Trustee a written request that the Trustee pursue a remedy with respect to such Event of Default;

(c) such Holder or Holders have offered and, if requested, provided, to the Trustee security or indemnity satisfactory to the Trustee against any loss, liability or other expense of compliance with such written request;

(d) the Trustee has not complied with such written request within 60 days after receipt of such written request and offer of security or indemnity; and

(e) during such 60-day period, the Holders of a majority of the aggregate principal amount of then outstanding Notes did not deliver to the Trustee a direction inconsistent with such written request.

A Holder may not use this Indenture to prejudice the rights of any other Holder or to obtain a preference or priority over any other Holder, it being understood that the Trustee does not have any affirmative duty to ascertain whether any usage of this Indenture by a Holder is unduly prejudicial to such other Holders.

Section 6.07 Rights of Holders To Receive Payment. Notwithstanding any other provision of this Indenture, the right of any Holder to receive payment of the principal or Terminal Value of, the Change of Control Repurchase Price or the Redemption Price, if any, for, the accrued and unpaid interest, if any, on, and any consideration due under Article 11 upon conversion of, its Note, on or after the respective due date, or to bring suit for the enforcement of any such payment and/or delivery on or after the respective due date, will not be impaired or affected without the consent of such Holder and will not be subject to the requirements of Section 6.06 hereof.

Section 6.08 Collection Suit by Trustee. If an Event of Default specified in Section 6.01(a)(i), 6.01(a)(ii) or 6.01(a)(iii) hereof occurs and is continuing, the Trustee is authorized to recover judgment in its own name and as trustee of an express trust against the Company or any Guarantor for the whole amount of any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and accrued and unpaid interest on, the Notes, and, to the extent lawful, any Default Interest on any Defaulted Amounts, and such further amount as is sufficient to cover the costs and expenses of collection provided for under Section 7.06 hereof.

Section 6.09 Trustee May File Proofs of Claim. The Trustee is authorized to file such proofs of claim and other papers or documents as may be necessary or advisable to have the claims of the Trustee and the Holders allowed in any judicial proceedings relative to the Company or any Guarantor, or the creditors or property of the Company or any Guarantor, and,

 

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unless prohibited by law or applicable regulations, will be entitled to collect, receive and distribute any money or other property payable or deliverable on any such claims, and any Custodian in any such judicial proceeding is hereby authorized by each Holder to make such payments to the Trustee, and in the event that the Trustee consents to the making of such payments directly to the Holders, to pay to the Trustee any amount due to it for the reasonable compensation, expenses, disbursements and advances of the Trustee, its agents and counsel, and any other amounts due the Trustee under Section 7.06 hereof. To the extent that the payment of any such compensation, expenses, disbursements and advances of the Trustee, its agents and counsel, and any other amounts due the Trustee under Section 7.06 hereof out of the estate in any such proceeding, will be denied for any reason, payment of the same will be secured by a Lien on, and will be paid out of, any and all distributions, dividends, money, securities and other properties that the Holders may be entitled to receive in such proceeding whether in liquidation or under any plan of reorganization or arrangement or otherwise. Nothing herein contained will be deemed to authorize the Trustee to authorize or consent to, or to accept or to adopt on behalf of any Holder, any plan of reorganization, arrangement, adjustment or composition affecting the Notes or the rights of any Holder, or to authorize the Trustee to vote in respect of the claim of any Holder in any such proceeding.

Section 6.10 Priorities . If the Trustee collects any money or property pursuant to this Article 6, it will pay out the money or property in the following order:

FIRST: to the Trustee, its agents and attorneys for amounts due under Section 7.06 hereof, including payment of all compensation, fees, expenses and liabilities incurred, and all advances made, by the Trustee and the costs and expenses of collection;

SECOND: to the Holders, for any amounts due and unpaid on the principal or Terminal Value of, the Change of Control Repurchase Price or Redemption Price for, and accrued and unpaid interest on, the Notes, without preference or priority of any kind, according to such amounts due and payable on all of the Notes; and

THIRD: the balance, if any, to the Company or the applicable Guarantor, or to such other party as a court of competent jurisdiction directs.

The Trustee may fix a record date and payment date for any payment to the Holders pursuant to this Section 6.10. If the Trustee so fixes a record date and a payment date, at least 15 days prior to such record date, the Company will deliver to each Holder and the Trustee a written notice, which notice will state such record date, such payment date and the amount of such payment, and if the Company is unable or refuses to do so, the Trustee will deliver such notice to each Holder.

Section 6.11 Undertaking for Costs. In any suit for the enforcement of any right or remedy under this Indenture or in any suit against the Trustee for any action taken or omitted by it as Trustee, a court in its discretion may require the filing by any party litigant in the suit of an undertaking to pay the costs of the suit, and the court in its discretion may assess reasonable costs, including reasonable attorneys’ fees and expenses, against any party litigant in the suit, having due regard to the merits and good faith of the claims or defenses made by the party litigant. This Section 6.11 does not apply to a suit by the Trustee, a suit by a Holder pursuant to Section 6.07 hereof or a suit by Holders of more than 10% in aggregate principal amount of the then outstanding Notes.

 

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ARTICLE 7

TRUSTEE

Section 7.01 Duties of Trustee.

(a) If an Event of Default has occurred and is continuing, the Trustee will exercise the rights and powers vested in it by this Indenture, and use the same degree of care and skill in its exercise as a prudent Person would exercise or use under the circumstances in the conduct of such Person’s own affairs.

(b) Except during the continuance of an Event of Default:

(i) the Trustee undertakes to perform such duties, and only such duties, as are specifically set forth in this Indenture, and no implied covenants or obligations will be read into this Indenture against the Trustee; and

(ii) in the absence of bad faith on its part, the Trustee may conclusively rely as to the truth of the statements and the correctness of the opinions expressed therein upon certificates or opinions furnished to the Trustee and conforming to the requirements of this Indenture.

(c) The Trustee may not be relieved from liabilities for its own negligent action, its own negligent failure to act, or its own willful misconduct, except that:

(i) this paragraph does not limit the effect of Section 7.01(b) hereof;

(ii) the Trustee will not be liable for any error of judgment made in good faith by a Responsible Officer unless it is proved that the Trustee was negligent in ascertaining the pertinent facts; and

(iii) the Trustee will not be liable with respect to any action it takes or omits to take in good faith in accordance with a direction received by it pursuant to Sections 6.05, 6.06, 13.02 or 13.03 hereof or any exercise in good faith of any trust or power conferred upon the Trustee under this Indenture with respect to the Notes.

(d) Whether herein expressly so provided, every provision of this Indenture that in any way relates to the Trustee is subject to Section 7.01(a), (b) and (c) hereof.

(e) The Trustee will not be liable for interest on any money received by it or risk or expend any of its own funds.

(f) Money held in trust by the Trustee need not be segregated from other funds except to the extent required by law.

 

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(g) No provision of this Indenture will require the Trustee to expend or risk its own funds or otherwise incur liability, financial or otherwise, in the performance of any of its duties hereunder or in the exercise of any of its rights or powers.

(h) Every provision of this Indenture relating to the conduct or affecting the liability of or affording protection to the Trustee will be subject to the provisions of this Article 7, and the provisions of this Article 7 will apply to the Trustee, Registrar, Paying Agent and Conversion Agent.

(i) The Trustee will not be deemed to have notice of a Default or an Event of Default unless (i) a Responsible Officer has received written notice at its Corporate Trust Office thereof from the Company or any Holder and such notice references the Notes and this Indenture or (ii) a Responsible Officer has actual knowledge thereof.

Section 7.02 Rights of Trustee.

(a) The Trustee may conclusively rely upon any written resolution, certificate, statement, instrument, opinion, report, notice, request, direction, consent, order, bond, debenture, note, other evidence of indebtedness or other paper or document believed by it to be genuine and to have been signed or presented by the proper Person. The Trustee need not investigate any fact or matter stated in any written resolution, certificate, statement, instrument, opinion, report, notice, request, direction, consent, order, bond, debenture, note, other evidence of indebtedness or other paper or document. The Trustee may, however, in its discretion make such further inquiry or investigation into such facts or matters as it may see fit and, if the Trustee determines to make such further inquiry or investigation, it will be entitled to examine the books, records and premises of the Company or any Guarantor, personally or by agent or attorney and at the expense of the Company, and will incur no liability of any kind by reason of such inquiry or investigation.

(b) Before the Trustee acts or refrains from acting, it may require an Officers’ Certificate or an Opinion of Counsel or both. The Trustee will not be liable for any action it takes or omits to take in good faith in reliance on the Officers’ Certificate or Opinion of Counsel.

(c) The Trustee may act through agents, attorneys or custodians and will not be responsible for the misconduct or negligence of any agent, attorney or custodian appointed with due care.

(d) So long as the Trustee’s conduct does not constitute willful misconduct or negligence, the Trustee will not be liable for any action it takes or omits to take in good faith that it reasonably believes to be authorized or within the rights or powers conferred upon it by this Indenture.

(e) The Trustee may consult with counsel of its own selection, and the advice of such counsel or any Opinion of Counsel with respect to legal matters relating to this Indenture and the Notes will be full and complete authorization and protection from liability in respect to any action taken, omitted or suffered by it hereunder in good faith and in accordance with and reliance upon the advice or opinion of such counsel.

 

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(f) The permissive rights of the Trustee to do things enumerated in this Indenture will not be construed as a duty unless so specified herein.

(g) The Trustee will be under no obligation to exercise any of the rights or powers vested in it by this Indenture at the request or direction of any of the Holders pursuant to this Indenture, unless such Holders have offered to the Trustee security or indemnity satisfactory to the Trustee against the costs, expenses and liabilities that might be incurred by it in compliance with such request or direction.

(h) The rights, privileges, protections, immunities and benefits given to the Trustee, including its right to be indemnified, are extended to, and will be enforceable by, the Trustee in each of its capacities hereunder, and each agent, custodian and other Person employed to act hereunder, including the Registrar, Paying Agent and Conversion Agent.

(i) The Trustee may request that the Company deliver an Officers’ Certificate setting forth the names of individuals and/or titles of officers authorized at such time to take specified actions pursuant to this Indenture, which Officers’ Certificate may be signed by any Person authorized to sign an Officers’ Certificate, including any Person specified as so authorized in any such certificate previously delivered and not superseded.

(j) In no event will the Trustee be responsible or liable for special, indirect, punitive or consequential loss or damage of any kind whatsoever (including, but not limited to, loss of profit) irrespective of whether the Trustee has been advised of the likelihood of such loss or damage and regardless of the form of action.

(k) The Trustee shall not be required to give any bond or surety in respect of the performance of its powers and duties hereunder.

Section 7.03 Individual Rights of Trustee. The Trustee in its individual or any other capacity may become the owner or pledgee of Notes and may otherwise deal with the Company or any Affiliate of the Company with the same rights it would have if it were not Trustee. However, if the Trustee acquires any conflicting interest it must eliminate the conflict within 90 days or resign. Any Paying Agent, Registrar, Conversion Agent or co-registrar may do the same with like rights. However, the Trustee must comply with Section 7.09 hereof.

Section 7.04 Trustee’s Disclaimer. The Trustee will not be responsible for and makes no representation as to the validity, sufficiency, priority or adequacy of this Indenture or the Notes, it will not be accountable for the Company’s use of the proceeds from the Notes, and it will not be responsible for the recitals contained in this Indenture, which shall be deemed statements of the Company, or for any other statement of the Company in this Indenture or in any document issued in connection with the sale of the Notes or in the Notes other than the Trustee’s certificate of authentication.

Section 7.05 Notice of Defaults. If a Default occurs and is continuing and is actually known to a Responsible Officer, the Trustee will send to each Holder notice of the Default within 90 days after such Default first occurs, or, if it is not known to the Trustee at such time, as soon as practicable after it is actually known to a Responsible Officer; provided, however, that except in the case of a Default that is, or would lead to, an Event of Default described in

 

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6.01(a)(i), 6.01(a)(ii), Section 6.01(a)(iii) or Section 6.01(a)(iv) hereof, the Trustee may withhold the notice, and will be protected in so withholding, if and so long as it in good faith determines that withholding the notice is in the interests of Holders.

Section 7.06 Compensation and Indemnity.

(a) The Company will pay to the Trustee, from time to time, such compensation as will be agreed upon, from time to time, in writing for its services. The Trustee’s compensation will not be limited by any law on compensation of a trustee of an express trust. The Company will reimburse the Trustee upon request for all reasonable out-of-pocket fees and expenses incurred or made by it, including costs of collection, in addition to the compensation for its services. Such expenses will include the reasonable compensation, fees and expenses, disbursements and advances of the Trustee’s agents, counsel, accountants and experts. The Company will fully indemnify the Trustee (or any predecessor Trustee) against any and all loss, liability, claim, damage, fee or expense (including reasonable attorneys’ fees and expenses) incurred by it in connection with the acceptance and administration of this trust and the performance of its duties hereunder, including the costs and expenses of defending itself against any claim (whether asserted by the Company, any Holder or any other Person) or liability in connection with the exercise or performance of any of its powers or duties hereunder, or in connection with enforcing the provisions of this Section. The Trustee will notify the Company promptly of any claim for which it may seek indemnity. Failure by the Trustee to so notify the Company of any claim for which it may seek indemnity of which a Responsible Officer has actually received written notice will not relieve the Company of its obligations hereunder except to the extent such failure is adjudicated by a court of competent jurisdiction to have materially prejudiced the Company. The Company will defend the claim and the Trustee will cooperate in the defense. If the Trustee is advised by counsel that it may have available to it defenses that are in conflict with the defenses available to the Company, then the Trustee may have separate counsel, and the Company will pay the reasonable fees and expenses of such counsel. The Company will pay the reasonable fees and expenses of counsel to the Trustee incurred in evaluating whether such defense and/or conflict exists. The Company need not reimburse any expense or indemnify against any loss, liability or expense incurred by the Trustee through the Trustee’s own willful misconduct or negligence. The Company need not pay for any settlement made by the Trustee without the Company’s consent, such consent not to be unreasonably withheld. All indemnifications and releases from liability granted hereunder to the Trustee will extend to its officers, directors, employees, agents, attorneys, custodians, successors and assigns.

(b) To secure the Company’s payment obligations under this Section 7.06, the Trustee will have a senior claim to which the Notes are hereby made subordinate on all money or property held or collected by the Trustee, other than money or property held in trust to pay the principal or Terminal Value of, the Change of Control Repurchase Price or Redemption Price, if any, for, and the accrued and unpaid interest, if any, on particular Notes.

(c) The Company’s payment and indemnity obligations pursuant to this Section 7.06 will survive the resignation or removal of the Trustee and the discharge of this Indenture. If the Trustee incurs expenses or renders services after the occurrence of a Default specified in Sections 6.01(a)(ix) or 6.01(a)(x) hereof, the expenses (including the reasonable fees and expenses of its counsel) and the compensation for the services are intended to constitute expenses of administration under the Bankruptcy Law.

 

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Section 7.07 Replacement of Trustee.

(a) The Trustee may resign at any time by notifying the Company, in writing, at least 30 days prior to the proposed resignation. The Holders of a majority in aggregate principal amount of then outstanding Notes may remove the Trustee by so notifying the Trustee, in writing. The Company may remove the Trustee if:

(i) the Trustee fails to comply with Section 7.09 hereof;

(ii) the Trustee is adjudged bankrupt or insolvent or an order for relief is entered with respect to the Trustee under any Bankruptcy Law;

(iii) a receiver or other public officer takes charge of the Trustee or its property; or

(iv) the Trustee otherwise becomes incapable of acting.

(b) If the Trustee resigns, is removed by the Company or by the Holders of a majority in aggregate principal amount of the Notes then outstanding, or if a vacancy exists in the office of Trustee for any reason (the Trustee in such event being referred to herein as the retiring Trustee), the Company will promptly appoint a successor Trustee.

(c) A successor Trustee will deliver a written acceptance of its appointment to the retiring Trustee and to the Company. Thereupon, the resignation or removal of the retiring Trustee will become effective, and the successor Trustee will have all the rights, powers and duties of the Trustee under this Indenture. The successor Trustee will send a notice of its succession to Holders. The retiring Trustee will, upon payment of all of its costs and the costs of its agents and counsel, promptly transfer all property held by it as Trustee to the successor Trustee, subject to the Lien provided for in Section 7.06 hereof.

(d) If a successor Trustee does not take office within 60 days after the retiring Trustee resigns or is removed, the retiring Trustee, the Company or the Holders of at least 10% of the aggregate principal amount of the Notes then outstanding may petition, at the expense of the Company, any court of competent jurisdiction for the appointment of a successor Trustee.

(e) If the Trustee, after written request by any Holder, fails to comply with Section 7.09 hereof, such Holder may petition any court of competent jurisdiction for the removal of the Trustee and the appointment of a successor Trustee.

(f) Notwithstanding the replacement of the Trustee pursuant to this Section 7.07, the Company’s obligations under Section 7.06 hereof will continue for the benefit of the retiring Trustee.

 

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Section 7.08 Successor Trustee by Merger.

(a) If the Trustee consolidates with, merges or converts into, or transfers all or substantially all its corporate trust business or assets to, another corporation or banking association, the resulting, surviving or transferee corporation or banking association without any further act will be the successor Trustee.

(b) In case at the time such successor or successors by merger, conversion or consolidation to the Trustee succeeds to the trusts created by this Indenture, any of the Notes have been authenticated, but not delivered, any such successor to the Trustee may adopt the certificate of authentication of any predecessor Trustee, and deliver such Notes so authenticated; and, in case at that time any of the Notes have not been authenticated, any such successor to the Trustee may authenticate such Notes, either in the name of any predecessor Trustee hereunder or in the name of the successor to the Trustee.

Section 7.09 Eligibility; Disqualification. The Trustee will have (or, in the case of a corporation included in a bank holding company system, the related bank holding company will have) a combined capital and surplus of at least $100,000,000, as set forth in its (or its related bank holding company’s) most recent published annual report of condition.

Section 7.10 Trustee’s Application for Instructions from the Company. Any application by the Trustee for written instructions from the Company may, at the option of the Trustee, set forth in writing any action proposed to be taken or omitted by the Trustee under this Indenture and the date on and/or after which such action will be taken or such omission will be effective. The Trustee will not be liable to the Company for any action taken by, or omission of, the Trustee in accordance with a proposal included in such application on or after the date specified in such application (which date will not be less than three Business Days after the date any Officer actually receives such application, unless any such Officer has consented in writing to any earlier date), unless prior to taking any such action (or the effective date in the case of any omission), the Trustee has received written instructions in response to such application specifying the action to be taken or omitted.

ARTICLE 8

SATISFACTION AND DISCHARGE

Section 8.01 Satisfaction and Discharge. The Company may terminate the obligations under this Indenture and the Notes when:

(a) all Notes that have been authenticated, except lost, stolen or destroyed Notes that have been replaced or paid and Notes for whose payment money has been deposited in trust and thereafter repaid to the Company, have been delivered to the Trustee for cancellation;

(b) no Event of Default has occurred and is continuing on the first date on which all such Notes have been delivered to the Trustee for cancellation; and

(c) the Company has paid or caused to be paid all sums payable by it under this Indenture.

 

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After such delivery, the Trustee, upon receipt of a written request by the Company along with an Officers’ Certificate and an Opinion of Counsel stating that all conditions precedent to satisfaction and discharge have been satisfied, shall acknowledge in writing the discharge of the Company’s obligations under the Notes and this Indenture.

ARTICLE 9

AMENDMENTS, SUPPLEMENTS AND WAIVERS

Section 9.01 Without Consent of Holders. The Company and the Trustee may amend or supplement this Indenture or the Notes without the consent of any Holder:

(a) to add Guarantees with respect to the Company’s obligations under this Indenture or the Notes;

(b) to secure the Notes;

(c) to provide for the assumption of the Company’s obligations under this Indenture and under the Notes by a Reorganization Successor Corporation as described in Article 5 hereof;

(d) to surrender any right or power conferred upon the Company under this Indenture;

(e) to add to the Company’s covenants or Events of Default for the benefit of the Holders;

(f) to cure any ambiguity or correct any inconsistency or defect in this Indenture or in the Notes that does not adversely affect Holders;

(g) to comply with any requirement of the SEC in connection with any qualification of this Indenture under the Trust Indenture Act of 1939;

(h) to evidence the acceptance of appointment by a successor Trustee with respect to this Indenture;

(i) to comply with the rules of any applicable Depositary;

(j) to conform the provisions of this Indenture to the “Description of Notes” section of the Offering Memorandum, as evidenced in an Officers’ Certificate;

(k) to make any other change; provided that such change individually, or in the aggregate with all other such changes, does not have, and will not have, an adverse effect on the interest of the Holders.

 

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Section 9.02 With Consent of Holders. With the written consent of the Holders of at least a majority of the aggregate principal amount of the Notes then outstanding (including consents obtained in connection with a repurchase of, or tender offer or exchange offer for, Notes), by Act of such Holders delivered to the Company and the Trustee, the Company, when authorized by a Board Resolution, may amend or supplement this Indenture or the Notes or waive compliance with any provision of this Indenture or the Notes; provided, however, that, without the consent of each affected Holder, no amendment or supplement to this Indenture or the Notes, or waiver of any provision of this Indenture or the Notes, may:

(a) reduce the principal amount of, or change the Maturity Date of, any Note;

(b) reduce the Terminal Value of any Note;

(c) reduce the rate of, or extend the stated time for payment of, interest on any Note;

(d) reduce the Change of Control Repurchase Price or the Redemption Price of any Note or change the time at which, or the circumstances under which, the Notes may, or will be, redeemed or repurchased;

(e) impair the right of any Holder to institute suit for any payment on any Note, including with respect to any consideration due upon conversion of a Note;

(f) make any Note payable in a currency other than that stated in the Note;

(g) make any change that impairs or adversely affects the conversion rights of any Holder under Article 11 hereof or otherwise reduces the number of shares of Common Stock, amount of cash or any other property receivable by a Holder upon conversion;

(h) change the ranking of the Notes;

(i) reduce any voting requirements included in this Indenture;

(j) make any change to any amendment, modification or waiver provision of this Indenture that requires the consent of each affected Holder; or

(k) reduce the percentage of the aggregate principal amount of then outstanding Notes whose Holders must consent to an amendment of this Indenture or a waiver of a past default;

provided, however, that any amendment to, or waiver of, the provisions of this Indenture relating to subordination that adversely affects the rights of the Holders will be subject to Section 10.14.

It will not be necessary for the consent of the Holders under this Section 9.02 to approve the particular form of any proposed amendment, but it will be sufficient if such consent approves the substance of such proposed amendment.

Section 9.03 Execution of Supplemental Indentures. Upon the written request of the Company, the Trustee will sign any supplemental indenture authorized pursuant to this Article 9 if the amendment contained therein does not affect the rights, duties, liabilities or immunities of the Trustee under this Indenture. If the supplemental indenture adversely affects the Trustee’s rights, duties, liabilities or immunities under this Indenture, then the Trustee may, but need not, sign such supplemental indenture. In executing any such supplemental indenture, the Trustee will be provided with, and, subject to the provisions of Section 7.01 hereof, will be fully protected in conclusively relying upon, an Officers’ Certificate and an Opinion of Counsel that

 

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comply with Sections 13.02 and 13.03 hereof and state that such supplemental indenture is (i) authorized and permitted under this Indenture and (ii) the legal, valid and binding obligation of the Company enforceable against each of them in accordance with its terms.

Section 9.04 Notices of Amendment or Supplemental Indentures. After an amendment or supplement to this Indenture or the Notes pursuant to Sections 9.01 or 9.02 hereof becomes effective, the Company will promptly deliver written notice to the Trustee, which notice will briefly describe the substance of such amendment or supplement to this Indenture in reasonable detail and state the effective date of such amendment or supplement. The Company, or the Trustee, at the written direction of the Company, will then promptly deliver a copy of such notice to each Holder. The failure to deliver such notice to each Holder, or any defect in such notice, will not impair or affect the validity of such amendment or supplement to this Indenture.

Section 9.05 Effect of Supplemental Indentures. Upon the execution of any supplemental indenture under this Article 9:

(a) this Indenture will be modified in accordance therewith;

(b) such supplemental indenture will form a part of this Indenture for all purposes; and

(c) every Holder will be bound thereby.

Section 9.06 Revocation and Effect of Consents, Waivers and Actions.

(a) Revocation. Until an amendment, supplement or waiver becomes effective, a consent to it by a Holder is a continuing consent by the Holder, and every subsequent Holder of a Note or portion of a Note that evidences the same debt as the consenting Holder’s Note, even if notation of the consent is not made on any Note. However, any such Holder, or subsequent Holder, may revoke the consent as to its Note or portion of a Note if the Trustee receives the notice of revocation before the date the amendment, supplement or waiver becomes effective.

(b) Special Record Dates. The Company may, but is not obligated to, fix a record date for the purpose of determining the Holders entitled to give their consent or take any other action described above or required, or permitted, to be taken pursuant to this Indenture. If a record date is fixed, then those Persons who were Holders at such record date (or their duly designated proxies), and only those Persons, will be entitled to give such consent, to revoke any consent previously given or to take any such action, regardless of whether such Persons continue to be Holders after such record date. No such consent will be valid or effective for more than 120 days after such record date.

(c) Binding Effect. After an amendment, supplement or waiver becomes effective, it will bind every applicable Holder. Any amendment or supplement will become effective in accordance with the terms of the supplemental indenture relating thereto, which will become effective upon the execution thereof by the Company and the Trustee.

Section 9.07 Notation on, or Exchange of, Notes. If any amendment, supplement or waiver changes the terms of a Note, the Trustee may require the Holder of such Note to deliver

 

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such Note to the Trustee. The Trustee may place an appropriate notation on such Note about the changed terms and return it to the Holder. Alternatively, if the Company or the Trustee so determines, the Company, in exchange for the Note, will issue and the Trustee will authenticate a new Note that reflects the changed terms.

ARTICLE 10

SUBORDINATION

Section 10.01 Agreement to Subordinate. The Company agrees, and each Holder by accepting a Note agrees, that the indebtedness evidenced by the Notes is subordinated in right of payment, to the extent and in the manner provided in this Article 10, to the prior payment in full of all amounts due and payable in respect of all Senior Debt (whether outstanding on the date hereof or hereafter created, incurred, assumed or guaranteed), and that the subordination is for the benefit of the holders of Senior Debt.

Section 10.02 Liquidation; Dissolution; Bankruptcy. Upon any distribution to creditors of the Company in a liquidation or dissolution of the Company, or in a bankruptcy, reorganization, insolvency, receivership, arrangement, adjustment, composition or similar proceeding relating to the Company, the Subsidiaries or their respective property, in an assignment for the benefit of creditors or any marshaling of the Company’s assets and liabilities:

(a) holders of Senior Debt will be entitled to receive payment in full of all principal, interest, penalties, fees, indemnifications, reimbursements, damages and other liabilities payable under the documentation governing any indebtedness due in respect of such Senior Debt (including interest after the commencement of any bankruptcy proceeding at the rate specified in the applicable Senior Debt), or provision shall be made for such payment in cash or cash equivalents or otherwise in a manner satisfactory to the holders of such Senior Debt, before the Holders will be entitled to receive any payment or distribution of any kind, whether in cash, property or securities with respect to the Notes; and

(b) until all principal, interest, penalties, fees, indemnifications, reimbursements, damages and other liabilities payable under the documentation governing any indebtedness due with respect to Senior Debt (as provided in clause (i) above) are paid in full, any payment or distribution to which Holders would be entitled but for this Article 10 will be made to holders of Senior Debt, as their interests may appear.

Section 10.03 Default on Designated Senior Debt.

(a) The Company may not make any payment or distribution to the Trustee or any Holder in respect of principal, interest, penalties, fees, indemnifications, reimbursements, damages and other liabilities payable under the documentation governing any indebtedness due with respect to the Notes and may not acquire from the Trustee or any Holder any Notes for cash or property until all principal and other principal, interest, penalties, fees, indemnifications, reimbursements, damages and other liabilities payable under the documentation governing any indebtedness due with respect to the Senior Debt have been paid in full if:

(i) a payment default on any Designated Senior Debt occurs and is continuing; or

 

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(ii) any other default occurs and is continuing on any series of Designated Senior Debt that permits holders of that series of Designated Senior Debt to accelerate its maturity and the Trustee receives a written notice of such default (a “Payment Blockage Notice”) from the Company or the holders of any Designated Senior Debt. If the Trustee receives any such Payment Blockage Notice, no subsequent Payment Blockage Notice will be effective for purposes of this Section 10.03 unless and until (A) at least 360 days have elapsed since the delivery of the immediately prior Payment Blockage Notice and (B) all scheduled payments of any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, interest on the Notes that have come due have been paid in full in cash.

No nonpayment default that existed or was continuing on the date of delivery of any Payment Blockage Notice to the Trustee may be, or may be made, the basis for a subsequent Payment Blockage Notice unless such default has been cured or waived for a period of not less than 90 days.

(b) The Company may and will resume payments on and distributions in respect of the Notes and may acquire them upon the earlier of:

(i) in the case of a payment default, upon the date upon which such default is cured or waived, and

(ii) in the case of a nonpayment default, upon the earlier of the date on which such nonpayment default is cured or waived and 179 days after the date on which the applicable Payment Blockage Notice is received, unless the maturity of any Designated Senior Debt has been accelerated,

if this Article 10 otherwise permits such payment, distribution or acquisition at the time of such payment, distribution or acquisition.

Section 10.04 Acceleration of Notes. If payment of the Notes is accelerated because of an Event of Default, the Company will promptly notify holders of Senior Debt of the acceleration.

Section 10.05 When Distribution Must Be Paid Over. In the event that the Trustee or any Holder of the Notes receives any payment of any obligations with respect to the Notes at a time when the payment is prohibited by Section 10.03 hereof and a Responsible Officer or the Holder, as applicable, has actual knowledge that the payment is prohibited by Section 10.03 hereof, such payment will be held by the Trustee or such Holder, in trust for the benefit of, and will be paid forthwith over and delivered, upon written request, to, the holders of Senior Debt as their interests may appear, their Representative under the agreement, indenture or other document (if any) pursuant to which Senior Debt may have been issued, as their respective interests may appear, the trustee in bankruptcy, receiver, liquidating trustee or custodian for application to the payment of all obligations with respect to Senior Debt remaining unpaid to the extent necessary to pay such obligations in full in accordance with their terms, after giving effect to any concurrent payment or distribution to or for the holders of Senior Debt.

 

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With respect to the holders of Senior Debt, the Trustee undertakes to perform or to observe only those obligations or covenants on the part of the Trustee as are specifically set forth in this Article 10, and no implied covenants or obligations with respect to the holders of Senior Debt will be read into this Indenture against the Trustee. The Trustee will not be deemed to owe any fiduciary duty to the holders of Senior Debt, and will not be liable to any such holders if the Trustee pays over or distributes to or on behalf of Holders or the Company or any other Person money or assets to which any holders of Senior Debt are then entitled by virtue of this Article 10, except if such payment is made as a result of the willful misconduct or gross negligence of the Trustee.

Section 10.06 Notice by the Company. The Company will promptly notify the Trustee and the Paying Agent in writing of any facts known to the Company that would cause a payment of any obligations with respect to the Notes to violate this Article 10 or would prohibit the making of any payment to or by the Trustee in respect of the Notes, but failure to give such notice will not affect the subordination of the Notes to the Senior Debt as provided in this Article 10.

Section 10.07 Subrogation. Until the Notes are paid in full, Holders will be subrogated (equally and ratably with all other indebtedness pari passu with the Notes) to the rights of holders of Senior Debt to receive distributions applicable to Senior Debt to the extent that distributions otherwise payable to the Holders have been applied to the payment of Senior Debt. A distribution made under this Article 10 to holders of Senior Debt that otherwise would have been made to Holders is not, as between the Company and Holders, a payment by the Company on the Notes.

Section 10.08 Relative Rights. This Article 10 defines the relative rights of Holders and holders of Senior Debt. Nothing in this Indenture will:

(i) impair, as between the Company and Holders, the obligations of the Company, which are absolute and unconditional, to pay any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and interest on, the Notes in accordance with their terms;

(ii) affect the relative rights of Holders and creditors of the Company other than their rights in relation to holders of Senior Debt;

(iii) prevent the Trustee or any Holder from exercising its available remedies upon a Default or Event of Default, subject to the rights of holders and owners of Senior Debt to receive distributions and payments otherwise payable to Holders; or

(iv) prevent the conversion of the Notes into Conversion Shares pursuant to, and in accordance with, the provisions of Article 11.

If the Company fails because of this Article 10 to pay any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and interest on, the Notes on the due date, the failure is still a Default or Event of Default.

Section 10.09 Subordination May Not Be Impaired. No right of any present or future

 

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holder of Senior Debt to enforce the subordination of the indebtedness evidenced by the Notes may be impaired by any act or failure to act by the Company, any such holder or any Holder or by the failure of the Company or any Holder to comply with this Indenture, regardless of any knowledge thereof that any such holder may have or be otherwise charged with.

Section 10.10 Distribution or Notice to Representative. Whenever a distribution is to be made or a notice given to holders of Senior Debt, the distribution may be made and the notice given to such holders’ Representative.

Section 10.11 Reliance on Judicial Order or Certificate. Upon any payment or distribution of assets of the Company referred to in this Article 10, the Trustee and the Holders will be entitled to conclusively rely upon any order or decree made by any court of competent jurisdiction or upon any certificate of such Representative or of the liquidating trustee or agent or other Person making any distribution to the Trustee or to the Holders for the purpose of ascertaining the Persons entitled to participate in such distribution, the holders of the Senior Debt and other indebtedness of the Company, the amount thereof or payable thereon, the amount or amounts paid or distributed thereon and all other facts pertinent thereto or to this Article 10.

Section 10.12 Rights of Trustee and Paying Agent. Notwithstanding the provisions of this Article 10 or any other provision of this Indenture, the Trustee will not be charged with knowledge of the existence of any facts that would prohibit the making of any payment or distribution by the Trustee, and the Trustee and the Paying Agent may continue to make payments on the Notes, unless a Responsible Officer of the Trustee has received at its Corporate Trust Office at least five Business Days prior to the date of such payment written notice of facts that would cause the payment of any obligations with respect to the Notes to violate this Article 10 and prior to the receipt of any such written notice, the Trustee shall be entitled in all respects to assume that no such facts exist; provided, however, that if a Responsible Officer of the Trustee shall not have received, at least three Business Days prior to the date upon which by the terms hereof any such money may become payable for any purpose (including, without limitation, the payment of the principal amount, issue price, Redemption Price, purchase price, Change in Control Purchase Price or interest, if any and in each case to the extent applicable, as the case may be, in respect of the Notes), the notice with respect to such money provided for in this Article 10, then, anything herein contained to the contrary notwithstanding, the Trustee shall have full power and authority to receive such money and to apply the same to the purpose for which such money was received and shall not be affected by any notice to the contrary which may be received by it within three Business Days prior to such date. Only the Company or a Representative may give the notice. Nothing in this Article 10 will impair the claims of, or payments to, the Trustee under or pursuant to Section 7.06 hereof.

Subject to the provisions of Section 7.01, the Trustee shall be entitled to conclusively rely on the delivery to it of a written notice by a Representative to establish that a notice has been given by a holder of Senior Debt (or a trustee or agent on behalf of any such holder). In the event that the Trustee determines in good faith that further evidence is required with respect to the right of Representative to participate in any payment or distribution pursuant to this Article 10, the Trustee may request such Person to furnish evidence to the reasonable satisfaction of the Trustee as to the amount of Senior Debt held by the Representative, the extent to which the Representative is entitled to participate in such payment or distribution and any other facts

 

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pertinent to the rights of such Person under this Article 10, and if such evidence is not furnished, the Trustee may defer any payment which it may be required to make for the benefit of the Representative pursuant to the terms of this Indenture pending judicial determination as to the rights of such Person to receive such payment.

The Trustee in its individual or any other capacity may hold Senior Debt with the same rights as set forth in this Article 10 as it would have if it were not Trustee. Any agent of the Trustee may do the same with like rights.

Section 10.13 Authorization to Effect Subordination. Each Holder, by the Holder’s acceptance of a Note, authorizes and directs the Trustee on such Holder’s behalf to take such action as may be necessary or appropriate to effectuate the subordination as provided in this Article 10, and appoints the Trustee to act as such Holder’s attorney-in-fact for any and all such purposes. If the Trustee does not file a proper proof of claim or proof of debt in the form required in any proceeding referred to in Section 6.09 hereof at least 30 days before the expiration of the time to file such claim, the Representatives are hereby authorized to file an appropriate claim for and on behalf of the Holders.

Section 10.14 Amendments. The provisions of this Article 10 may not be amended or modified without the written consent of the holders of all Senior Debt. In addition, any amendment to, or waiver of, the provisions of this Article 10 that adversely affects the rights of the Holders will require the consent of the Holders of at least 75% in aggregate principal amount of Notes then outstanding.

ARTICLE 11

CONVERSION

Section 11.01 Right To Convert Upon a Qualified PO.

(a) General. Each Holder will have the option to elect to convert all or a portion of its Notes, having a principal amount equal to $1,000 or an integral multiple of $1,000 in excess thereof, into shares of Common Stock (“Conversion Shares”) at any time during the period beginning on the Business Day immediately following a Qualified PO Filing Date and ending on a date no less than 30 Business Days thereafter that is set by the Company by notice to the Holders (such date, the “Conversion Deadline”). The Company will provide the Holders, the Trustee and the Conversion Agent (if other than the Trustee) with written notice of the Qualified PO Filing Date and issue a press release announcing the same no later than the Business Day immediately following the Qualified PO Filing Date. Such notice will include the applicable Conversion Deadline.

Section 11.02 Conversion Procedures.

(a) General. To exercise its conversion right with respect to a beneficial interest in a Global Note, the owner of such beneficial interest must (i) comply with the Applicable Procedures for converting such beneficial interest; and (ii) pay any taxes or duties that such Holder is required to pay under the proviso to Section 11.02(d) hereof.

 

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To exercise its conversion right with respect to a Certificated Note, the Holder of such Note must (i) complete and manually sign the conversion notice on the back of the Note, or a facsimile of such conversion notice (such notice, or such facsimile, the “Conversion Notice”); (ii) deliver such signed and completed Conversion Notice and such Note to the Conversion Agent at its office; (iii) furnish any endorsements and transfer documents that the Company, Conversion Agent, Trustee or Transfer Agent may require; and (iv) pay any transfer taxes or similar duties that such Holder is required to pay under the proviso to Section 11.02(d) hereof.

For each Note with regard to which a Holder satisfies the foregoing requirements and which conversion of such Note is not otherwise prohibited under this Indenture, the closing date of the Qualified PO will be the “Conversion Date” for such Note.

The conversion of any Note will be deemed to occur at the Open of Business on the Conversion Date for such Note, and any converted Note or portion thereof will cease to be outstanding upon conversion.

(b) Termination of Election of Conversion. Any Conversion Notice shall be irrevocable, subject only to the closing of a Qualified PO no later than one year from the applicable Qualified PO Filing Date or an earlier determination by the Company that it no longer intends to consummate such Qualified PO. The Conversion Notice will be void in the event:

(i) such Qualified PO is not closed within one year from the applicable Qualified PO Filing Date; or

(ii) the Company provides notice to Holders and the Conversion Agent that it no longer intends to consummate such Qualified PO.

The Company will provide the Holders and the Conversion Agent the notice referred to in the foregoing clause (ii) promptly after it makes the determination not to consummate the Qualified PO, but, for the avoidance of doubt, such determination will be in the Company’s sole discretion.

(c) Conversions in Part. If a Holder surrenders only a portion of the principal amount of a Certificated Note for conversion, promptly after the Conversion Date, the Company will, in accordance with Section 2.05 hereof, execute and deliver to the Trustee, and the Trustee will, upon receipt of a Company Order and the documents required by Sections 13.02 and 13.03 hereof, in accordance with Section 2.05 hereof, authenticate and deliver to such Holder a new Certificated Note in an authorized denomination, having a principal amount equal to the aggregate principal amount of the unconverted portion of the Certificated Note surrendered for conversion and bearing registration numbers not contemporaneously outstanding and any restrictive legends that such Certificated Note must bear under Section 2.10 hereof.

Upon the conversion of any beneficial interest in a Global Note, the Conversion Agent will promptly request that the Trustee make a notation on the “Schedule of Increases and Decreases of Global Note” of such Global Note to reduce the principal amount represented by such Global Note by the principal amount of the converted beneficial interest. If all of the beneficial interests in a Global Note are so converted, such Global Note will be deemed surrendered to the Trustee for cancellation, and the Trustee will cause such Global Note to be cancelled in accordance with the Applicable Procedures and the Trustee’s internal procedures.

 

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(d) Taxes and Duties. If a Holder converts a Note, the Company will pay any documentary, stamp or similar issue or transfer tax due on the issue of any shares of the Common Stock upon the conversion; provided, however, that if any such tax is due because the converting Holder requested that shares of Common Stock be issued in a name other than its own, such Holder will pay such tax. Such Common Stock shall not be issued or delivered unless all such taxes, if any, payable by the Holder have been paid.

(e) Notices. The Conversion Agent will, as promptly as possible following the Conversion Date, and in no event later than the Business Day immediately following the Conversion Date, deliver to the Company and the Trustee notice that the Conversion Date has occurred, which notice will state the Conversion Date, the principal amount of Notes converted on the Conversion Date and the names of the Holders that converted Notes on the Conversion Date.

The Company will provide each Holder that elects to convert all or a portion of its Notes into Conversion Shares with written notice of the effective date of the registration statement filed under the Securities Act in connection with the applicable Qualified PO no later than the Business Day immediately following the effective date. The notice will include the expiration date of the period beginning on the Conversion Deadline and ending on the day that is 180 days after the pricing date of the Qualified PO (the “Lock-up Period”).

(f) Notes subject to a Conversion Notice. Notwithstanding anything to the contrary contained herein, once a Conversion Notice has been signed and delivered in accordance with Section 11.02(a), each Note subject to such Conversion Notice may not be transferred or sold by the Holder thereof (other than as required in order to consummate the conversion of such Note in accordance with this Article 11) unless and until the Company provides notice to Holders and the Conversion Agent that it no longer intends to consummate such Qualified PO in accordance with Section 11.02(b)(ii).

Section 11.03 Settlement Upon Conversion.

(a) Conversion Obligation.

(i) Calculation of Conversion Shares. Upon conversion, a Holder will receive such Holder’s Pro Rata Portion of a number of Conversion Shares equal to the greater of:

 

  (A) the Qualified PO Principal Amount divided by the Applicable Conversion Price. The “Applicable Conversion Price” will be the public offering price per share of Common Stock in the Qualified PO multiplied by the applicable percentage of public offering price set forth in the table below determined as of the pricing date of the Qualified PO.

 

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Pricing Date of Qualified PO

   Percentage of Public
Offering Price
 

On or before December 31, 2014

     90

January 1, 2015 to June 30, 2015

     86

July 1, 2015 to December 31, 2015

     78

January 1, 2016 to June 30, 2016

     73

July 1, 2016 to December 31, 2016

     68

January 1, 2017 to June 30, 2017

     63

July 1, 2017 to December 31, 2017

     58

January 1, 2018 to June 30, 2018

     53

July 1, 2018 to December 31, 2018

     48

On or after January 1, 2019

     45

and

 

  (B) the difference between (A) the Pre-Qualified PO Share Number divided by one minus a fraction, the numerator of which is the Qualified PO Principal Amount and the denominator of which is the Upside Trigger and (B) the Pre-Qualified PO Share Number.

(ii) Delivery of Conversion Shares. The Company will not issue any fractional shares of Common Stock upon conversion of the Notes and the number of Conversion Shares will be rounded up or down to the nearest whole number of shares. The Company will pay in cash accrued and unpaid interest on the Notes to, but not including, the closing date of the Qualified PO. The Conversion Shares and accrued and unpaid interest will be delivered or paid, as applicable, to the Holder thereof on the closing date of the Qualified PO. Holders will become the record holders of the Conversion Shares so delivered as of the Open of Business on such closing date.

(b) Conversion of Multiple Notes by a Single Holder. If a Holder converts more than one Note on a single Conversion Date, the Conversion Shares due in respect of such conversion will be computed based on the total principal amount of Notes converted on such Conversion Date by such Holder.

Section 11.04 Common Stock Issued Upon Conversion.

(a) Prior to issuing of any shares of Common Stock under this Article 11, and from time to time thereafter as may be necessary, the Company will reserve out of its authorized but unissued shares of Common Stock a number of shares of Common Stock sufficient to permit the conversion of all Notes with respect to which conversion rights have been exercised in accordance with Section 11.02.

(b) Any shares of Common Stock delivered upon the conversion of the Notes will be newly issued shares or treasury shares, duly and validly issued, fully paid, nonassessable, free from preemptive rights and free of any lien or adverse claim (except to the extent of any lien or adverse claim created by the action or inaction of the Holder or other Person to whom such shares of Common Stock will be delivered). In addition, the Company will endeavor to comply promptly with all federal and state securities laws regulating the offer and delivery of any shares of Common Stock issuable upon conversion of the Notes. Other than as set forth in the Registration Rights Agreement, the Company will not be obligated to register the offer and sale of such Common Stock under the Securities Act or any other applicable securities laws.

 

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(c) If any shares of the Common Stock issued upon conversion will, upon delivery as part of the conversion obligation, be “restricted securities” (within the meaning of Rule 144 or any successor provision in effect at such time), such shares of Common Stock (i) will be issued in physical, certificated form; (ii) will not be held in book-entry form through the facilities of the Depositary; and (iii) will bear any restrictive legends the Company or the Transfer Agent deem necessary to comply with applicable law.

Section 11.05 Adjustment of Upside Trigger.

(a) If at any time or from time to time after the date hereof and before the closing of a Qualified PO, the Company shall sell (an “Equity Sale”) to any Person the Company’s Capital Stock or any securities convertible into or exchangeable for the Company’s Capital Stock, whether or not the rights to exchange or convert thereunder are immediately exercisable (“Convertible Securities”), then if the Closing Date Equity Value is greater than the Upside Trigger, the Upside Trigger will be increased based on the following formula:

 

LOGO

where

 

VT1 =

   the Upside Trigger in effect immediately after the closing of the Equity Sale.

VT0 =

   the Upside Trigger in effect immediately prior to the closing of the Equity Sale.

GP  =

   the gross proceeds to the issuer from the Equity Sale.

EV  =

   the Closing Date Equity Value.

(b) Successive Adjustments. After an adjustment to the Upside Trigger under this Article 11, any subsequent event requiring an adjustment under this Article 11 will cause an adjustment to the Upside Trigger as so adjusted, without duplication.

(c) Restrictions on Adjustments. Notwithstanding the foregoing, no adjustment to the Upside Trigger will be made pursuant to this Section 11.05(a) if the Upside Trigger would be increased by less than $2,000,000 as a result of the adjustment.

In addition, notwithstanding anything to the contrary elsewhere in this Indenture, the Upside Trigger will not be adjusted as a result of the issuance of any of the following:

(i) Capital Stock upon the conversion of any Convertible Securities outstanding on the Issue Date;

 

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(ii) Capital Stock or Convertible Securities issued or issuable by reason of a dividend, stock split, split-up or other distribution on Capital Stock and Capital Stock issued or deemed issued as a dividend or distribution on Capital Stock;

(iii) Capital Stock and/or options, warrants or rights to purchase Capital Stock and the Capital Stock issued pursuant to such options, warrants or other rights to employees, consultants, officers or directors pursuant to any stock plans, equity incentive plans, restricted stock plans or other similar arrangements;

(iv) Capital Stock or Convertible Securities to lenders, financial institutions, equipment lessors, landlords, brokers or similar entities in connection with commercial credit arrangements, equipment financings, commercial property lease transactions or similar transactions;

(v) Capital Stock or Convertible Securities to suppliers or third party service providers in connection with the provision of goods or services; or

(vi) Capital Stock or Convertible Securities in connection with any settlement of any action, suit, proceeding or litigation.

(d) Notices. Upon the occurrence of each adjustment or other determination of the Upside Trigger pursuant to this Section 11.05, the Company will promptly as reasonably practicable compute such adjustment and the Company will (a) furnish to the Trustee, the Paying Agent, the Conversion Agent and each of the Holders an Officers’ Certificate setting forth such adjustment and showing in reasonable detail the facts upon which such adjustment or other determination is based, which Officers’ Certificate each of the Trustee, the Paying Agent and the Conversion Agent may treat as conclusive evidence that the adjustment specified in such Officers’ Certificate is correct and will be in effect as of the effective time specified in such Officers’ Certificate and (b) furnish, upon written notice at any time of any Holder to such Holder a written notice, which notice will include (i) any and all adjustments or other determinations made to the Upside Trigger since the date of this Indenture and (ii) the Upside Trigger at that time in effect. The failure to deliver such notice will not affect the legality or validity of any such adjustment.

Section 11.06 No Responsibility of Trustee, Conversion Agent and Paying Agent. The Trustee, Conversion Agent and the Paying Agent will not have any duty or responsibility to calculate the Equity Value or the Upside Trigger or determine whether any facts exist that require an adjustment of the Upside Trigger, or with respect to the nature or extent or calculation of any such adjustment when made, or with respect to the method employed in making the same. None of the Trustee, the Paying Agent or the Conversion Agent will be responsible for any failure of the Company to deliver the Conversion Shares due upon the surrender of any Notes for the purpose of conversion or to comply with any of the duties, responsibilities or covenants of the Company contained in this Article 11.

 

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ARTICLE 12

REDEMPTION AT THE OPTION OF THE COMPANY

Section 12.01 No Sinking Fund; Notes Not Redeemable Prior to Qualified PO or Change of Control. No sinking fund is provided for the Notes. Prior to the earlier of the closing of a Qualified PO and a Change of Control Repurchase Date, the Company may not redeem the Notes.

Section 12.02 Right to Redeem in Connection with a Qualified PO. Prior to the Maturity Date, if the closing of a Qualified PO occurs, the Company has the option to redeem (a “Qualified PO Redemption Right”) all, but not less than all, of the Notes (a “Qualified PO Redemption”) that are not subject to a Conversion Notice on the Redemption Date for an amount of cash equal to the Redemption Price for such Redemption Date.

The Company shall give notice of its intention to exercise of the Qualified PO Redemption Right (a “Qualified PO Redemption Notice”) to the Holders during the period beginning on the Business Day following the Conversion Deadline and ending on the tenth Business Day thereafter. Any Qualified PO Redemption Notice shall be irrevocable, subject only to the closing of a Qualified PO no later than one year from the applicable Qualified PO Filing Date or an earlier determination that the Company no longer intends to consummate such Qualified PO. In the event (i) the Qualified PO giving rise to the Qualified PO Redemption Right is not closed within one year from the applicable Qualified PO Filing Date or (ii) the Company provides notice to Holders that it no longer intends to consummate such Qualified PO (a “Qualified PO Revocation Notice”), the Qualified PO Redemption Notice will be void. The Company will provide Holders a Qualified PO Revocation Notice promptly after the Company makes the determination, in the Company’s sole discretion, not to consummate the Qualified PO.

Section 12.03 Right to Redeem Following a Change of Control . On or following a Change of Control Repurchase Date, in the event that any Notes remain outstanding following such Change of Control Repurchase Date, the Company may redeem (a “Change of Control Redemption”) any such Notes that remain outstanding in whole but not in part, at any time at the Redemption Price for such Redemption Date. Any Change of Control Redemption and any related Redemption Notice may, in the Company’s discretion, be subject to the satisfaction or one or more conditions precedent.

Section 12.04 General. Redemption Notice. At least 30 calendar days but not more than 60 calendar days prior to any Redemption Date and, in the case of a Qualified PO Redemption, on a date following the closing date of the Qualified PO, the Company (with written notice to the Trustee, in the case of a Global Note, no less than one Business Day (or such shorter period as agreed by the Trustee), or, in the case of a Certificated Note, no less than 10 calendar days (or such shorter period as agreed by the Trustee) prior to the sending of such redemption notice in the event the Trustee is engaged by the Company to send such notice or cause such notice to be sent in the Company’s name and at the Company’s expense), in order to effect a Qualified PO Redemption or a Change of Control Redemption, will send to each Holder (and to any beneficial owner of a Global Note, as required by applicable law) a written notice of redemption (the “Redemption Notice,” and the date of such sending, the “Redemption Notice Date”) and, substantially contemporaneously therewith, the Company will issue a press release announcing such redemption.

 

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For any redemption, the Redemption Notice corresponding to such redemption will specify:

(i) a brief description of the Company’s redemption right under this Indenture;

(ii) the date specified for such redemption (the “Redemption Date”), which date must be a Business Day; provided that, for a Qualified PO Redemption, the Redemption Date must be not less than 30 calendar days, nor more than 60 calendar days, immediately following the date on which the closing of the Qualified PO occurs;

(iii) the redemption price for the Notes to be redeemed on such Redemption Date, which will be a price equal to 100% of the principal amount of the Notes to be redeemed, plus accrued and unpaid interest, if any, on such Notes to, but excluding, such Redemption Date (the “Redemption Price”); provided, however, that if a Redemption Date occurs after a Regular Record Date, but on or prior to the Interest Payment Date corresponding to such Regular Record Date, the Redemption Price for any Notes to be redeemed will equal 100% of the principal amount of such Notes, and accrued and unpaid interest, if any, on such Notes to, but excluding, such Redemption Date will be payable, on such Interest Payment Date, to the Holder of such Notes at the Close of Business on such Regular Record Date, and the Redemption Price shall not include such accrued and unpaid interest;

(iv) the name and address of the Paying Agent;

(v) that Notes must be surrendered to the Paying Agent on or before the Redemption Date to collect the Redemption Price;

(vi) that, unless the Company defaults in paying the Redemption Price on the Redemption Date, interest, if any, on a Note will cease to accrue on and after the Redemption Date;

(vii) the CUSIP and ISIN number(s) of the Notes;

(viii) that no representation is made as to the correctness or accuracy of the CUSIP and ISIN number(s), if any, listed in such notice or printed on the Notes; and

(ix) any conditions precedent applicable to the redemption.

The Company may provide in any Redemption Notice that payment of the Redemption Price and the performance of the Company’s obligations with respect to such redemption may be performed by another Person.

On any Redemption Notice Date, the Company will also furnish to the Trustee an Officers’ Certificate, which Officers’ Certificate will set forth the aggregate principal amount of Notes then outstanding and include a copy of the Redemption Notice delivered by the Company on such Redemption Notice Date.

 

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Section 12.05 Effect of Redemption Notice. After the Company has delivered a Redemption Notice, each Holder will have the right to receive payment of the Redemption Price for its Notes on the later of (i) the Redemption Date and (ii) (a) if the Notes are Certificated Notes, delivery of its Notes to the Paying Agent or (b) if the Notes are Global Notes, compliance with the Applicable Procedures relating to the redemption and delivery of the beneficial interests to be redeemed to the Paying Agent.

Section 12.06 Deposit of Redemption Price. Prior to 10:00 a.m., New York City time, on the Redemption Date, the Company will deposit with the Paying Agent (or, if the Company or any of the Subsidiaries is acting as the Paying Agent, will segregate and hold in trust as provided in Section 2.07 hereof) an amount of immediately available funds sufficient to pay the Redemption Price of all of the then-outstanding Notes.

Section 12.07 Effect of Deposit. If, as of 10:00 a.m., New York City time, on any Redemption Date, the Company, in accordance with Section 12.06 hereof, has deposited with the Paying Agent money sufficient to pay the Redemption Price for every Note validly delivered in accordance with Section 12.05 hereof, then, at the Close of Business on such Redemption Date:

(A) every Note outstanding immediately prior to the Close of Business on such Redemption Date will cease to be outstanding and interest, if any, on such Notes will cease to accrue (regardless of whether such Notes were delivered to the Paying Agent or book-entry transfer has been made, as applicable), except to the extent provided in the proviso to Section 12.04(a)(iii) hereof; and

(B) all other rights of the Holders of such Notes with respect to such Notes (other than the right to receive payment of the Redemption Price and other than as provided in the proviso to Section 12.04(a)(iii) hereof) will terminate.

Section 12.08 Covenant Not to Redeem Notes Upon Certain Events of Default.

(a) General. Notwithstanding anything to the contrary in this Article 12, the Company will not redeem any Notes under this Article 12 if the principal amount of the Notes has been accelerated and such acceleration has not been rescinded on, or prior to, the Redemption Date (except in the case of an acceleration resulting from a default by the Company that would be cured by the Company’s payment of the Redemption Price for such Notes).

(b) Return of Notes. If a Holder delivers a Note for redemption pursuant to Section 12.05 hereof and, on the Redemption Date, pursuant to this Section 12.08, the Company is not permitted to redeem such Note, the Paying Agent will (i) if such Note is a Certificated Note, return such Note to such Holder, and (ii) if such Note is held in book-entry form, in compliance with the Applicable Procedures, deem to be cancelled any instructions for book-entry transfer of such Note.

Section 12.09 Repayment to the Company. Subject to any applicable property laws, if, six months after the Redemption Date, any cash held by the Paying Agent remains unclaimed,

 

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the Paying Agent will promptly return such cash to the Company; provided, however, that, to the extent that the aggregate amount of cash deposited by the Company pursuant to Section 12.06 exceeds the aggregate Redemption Price of every Note outstanding, then as soon as practicable following the Redemption Date, the Trustee will return such excess to the Company.

ARTICLE 13

MISCELLANEOUS

Section 13.01 Notices. Any request, demand, authorization, notice, waiver, consent or communication will be in writing and delivered in Person or mailed by first-class mail, postage prepaid, addressed as follows or transmitted by facsimile transmission or other similar means of unsecured electronic methods (in PDF format) to the following:

if to the Company:

Energy & Exploration Partners, Inc.

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, TX 76102

Telephone: (817) 789-6712

Attention: Legal Department

with a copy to:

Charles H. Still, Jr.

Bracewell & Giuliani LLP

711 Louisiana Street, Suite 2300

Houston, Texas 77002

Telephone: (713) 221-3309

if to the Trustee, Registrar, Paying Agent or Conversion Agent:

U.S. Bank National Association

13737 Noel Road, Suite 800

Dallas, Texas 75240

Attention: Corporate Trust Services

The Company or the Trustee, by notice given to the other in the manner provided above, may designate additional or different addresses for subsequent notices or communications.

Any notice or communication given to a Holder will be mailed to the Holder, by first class mail, postage prepaid, at the Holder’s address as it appears on the registration books of the Registrar and will be deemed given on the date of such mailing; provided, however, that with respect to any Global Note, such notice or communication will be sent to the Holder thereof pursuant to the Applicable Procedures.

 

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Failure to mail or send a notice or communication to a Holder or any defect in it will not affect its sufficiency with respect to other Holders. If a notice or communication is mailed or sent in the manner provided above, it is duly given, whether or not received by the addressee.

If the Company mails or sends a notice or communication to the Holders, the Company will, at the same time, mail a copy to the Trustee and each of the Registrar, Paying Agent and Conversion Agent.

If the Company is required under this Indenture to give a notice to the Holders, in lieu of delivering such notice to the Holders, the Company may deliver such notice to the Trustee and cause the Trustee, at the Company’s expense, to have delivered such notice to the Holders on or prior to the date on which the Company would otherwise have been required to deliver such notice to the Holders. In such a case, the Company will also cause the Trustee to mail a copy of the notice to each of the Registrar, Paying Agent and Conversion Agent (if other than the Trustee) at the same time it sends the notice to the Holders.

Section 13.02 Certificate and Opinion as to Conditions Precedent. Upon any request or application by the Company to the Trustee to take any action under this Indenture, the Company will furnish to the Trustee:

(a) an Officers’ Certificate stating that, in the judgment or opinion of the signers, all conditions precedent, if any, provided for in this Indenture relating to the proposed action have been complied with; and

(b) other than the authentication of the initial Global Notes on the Issue Date, an Opinion of Counsel stating that, in the judgment or opinion of such counsel, all such conditions precedent relating to the proposed action (to the extent of legal conclusions and subject to reasonable assumptions and exclusions) have been complied with.

Section 13.03 Statements Required in Certificate or Opinion. Each Officers’ Certificate or Opinion of Counsel with respect to compliance with a covenant or condition (except for such Officers’ Certificate required to be delivered pursuant to Section 4.04 hereof) provided for in this Indenture will include:

(a) a statement that each Person making such Officers’ Certificate or Opinion of Counsel has read such covenant or condition;

(b) a brief statement as to the nature and scope of the examination or investigation upon which the statements, judgments or opinions contained in such Officers’ Certificate or Opinion of Counsel are based;

(c) a statement that, in the judgment or opinion of each such Person, such Person has made such examination or investigation as is necessary to enable such Person to express an informed judgment or opinion as to whether or not such covenant or condition has been complied with; and

(d) a statement that, in the judgment or opinion of such Person, such covenant or condition has been complied with.

 

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Section 13.04 Separability Clause. In case any provision in this Indenture or in the Notes will be invalid, illegal or unenforceable, the validity, legality and enforceability of the remaining provisions will not in any way be affected or impaired thereby.

Section 13.05 Rules by Trustee. The Trustee may make reasonable rules for action by, or a meeting of, Holders.

Section 13.06 Governing Law and Waiver of Jury Trial. THE INDENTURE AND EACH NOTE WILL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF NEW YORK. EACH OF THE COMPANY AND THE TRUSTEE HEREBY IRREVOCABLY WAIVES, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS INDENTURE, THE NOTES OR THE TRANSACTION CONTEMPLATED HEREBY.

Section 13.07 No Recourse Against Others. A director, officer, employee or stockholder, as such, of the Company will not have any liability for any obligations of the Company under the Notes or this Indenture or for any claim based on, in respect of or by reason of such obligations or their creation. By accepting a Note, each Holder waives and releases all such liability. The waiver and release are part of the consideration for the issuance of the Notes.

Section 13.08 Calculations. Except as otherwise provided in this Indenture, the Company will be responsible for making all calculations called for under the Notes and this Indenture. These calculations include, but are not limited to, determinations of the accrued interest payable on the Notes, the Closing Date Equity Value and the Conversion Shares.

The Company will make all calculations in good faith and, absent manifest error, its calculations will be final and binding on all Holders. The Company will provide a schedule of its calculations to each of the Trustee, the Paying Agent and the Conversion Agent, and each of the Trustee, the Paying Agent and Conversion Agent is entitled to rely conclusively upon the accuracy of the Company’s calculations without independent verification. If any Holder makes a written request to the Trustee for a copy of such schedule, the Trustee will promptly forward a copy of such schedule to such Holder.

All calculations will be made to the nearest cent (with 0.5 of a cent rounded upward) or to the nearest 1/10,000th of a share (with 5/100,000ths rounded upward), as the case may be.

Section 13.09 Successors. All agreements of the Company, the Trustee, the Registrar, the Paying Agent and the Conversion Agent in this Indenture and the Notes will bind their respective successors.

Section 13.10 Multiple Originals. The parties may sign any number of copies of this Indenture. Each signed copy will be an original, but all of them together represent the same agreement. One signed copy is enough to prove this Indenture. The exchange of copies of this Indenture and of signature pages by facsimile or PDF transmission will constitute effective execution and delivery of this Indenture as to the parties hereto and may be used in lieu of the original Indenture for all purposes. Signatures of the parties hereto transmitted by facsimile or PDF will be deemed to be their original signatures for all purposes.

 

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Section 13.11 Table of Contents; Headings. The table of contents and headings of the articles and sections of this Indenture have been inserted for convenience of reference only, are not intended to be considered a part hereof, and will not modify or restrict any of the terms or provisions hereof.

Section 13.12 Force Majeure. The Trustee, Registrar, Paying Agent and Conversion Agent will not incur any liability for not performing any act or fulfilling any duty, obligation or responsibility hereunder by reason of any occurrence beyond the control of such Person (including, but not limited to, any act or provision of any present or future law or regulation or governmental authority, any act of God or war, civil unrest, local or national disturbance or disaster, any act of terrorism, loss or malfunctions of utilities, communications or computer (software and hardware) services, or the unavailability of the Federal Reserve Bank wire or facsimile or other wire or communication facility).

Section 13.13 Submission to Jurisdiction. The Company: (a) agrees that any suit, action or proceeding against them arising out of or relating to this Indenture or the Notes, as the case may be, may be instituted in any U.S. federal court with applicable subject matter jurisdiction sitting in The City of New York; (b) waives, to the fullest extent permitted by applicable law, any objection which the Company may now or hereafter have to the laying of venue of any such suit, action or proceeding, and any claim that any suit, action or proceeding in such a court has been brought in an inconvenient forum; and (c) submits to the nonexclusive jurisdiction of such courts in any suit, action or proceeding.

Section 13.14 Legal Holidays. If the Maturity Date or any Interest Payment Date, Change of Control Repurchase Date, Redemption Date or Conversion Date is not a Business Day, then any action to be taken on such date need not be taken on such date, but may be taken on the immediately following Business Day with the same force and effect as if taken on such date, and no interest will accrue for the period from and after such date.

Section 13.15 No Security Interest Created. Except as provided in Section 7.06 or 9.01(b) hereof, nothing in this Indenture or in the Notes, expressed or implied, will be construed to constitute a security interest under the New York Uniform Commercial Code or similar legislation, as now or hereafter enacted and in effect, in any jurisdiction.

Section 13.16 Benefits of Indenture. Nothing in this Indenture or in the Notes, expressed or implied, will give to any Person, other than the parties hereto, any Paying Agent, Conversion Agent, Registrar, and their successors hereunder, and the Holders any benefit or any legal or equitable right, remedy or claim under this Indenture.

Section 13.17 U.S.A. Patriot Act. The parties hereto acknowledge that in accordance with Section 326 of the U.S.A. Patriot Act, the Trustee, like all financial institutions, in order to help fight the funding of terrorism and money laundering, is required to obtain, verify and record information that identifies each person or legal entity that establishes a relationship or opens an account with the Trustee. The parties to this Indenture agree that they will provide the Trustee with such information as it may request in order for the Trustee to satisfy the requirements of the U.S.A. Patriot Act.

 

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[Signature Pages Follow]

 

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IN WITNESS WHEREOF, the Company has caused this Indenture to be duly executed as a deed the day and year first before written.

ENERGY & EXPLORATION PARTNERS, INC.

 

By:  

/s/ Brian C. Nelson

  Name:   Brian C. Nelson
  Title:   Executive Vice President and
    Chief Financial Officer

 

Signature Page – Indenture


IN WITNESS WHEREOF, the undersigned, being duly authorized, has executed this Indenture as of the day and year first before written.

 

U.S. BANK NATIONAL ASSOCIATION,

as Trustee

By:  

/s/ Israel Lugo

  Name:   Israel Lugo
  Title:   Vice President

 

Signature Page – Indenture


EXHIBIT A

FORM OF NOTE

[FORM OF FACE OF NOTE]

[Include the following legend for Global Notes only:]

THIS IS A GLOBAL NOTE WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF THE DEPOSITARY OR A NOMINEE OF THE DEPOSITARY, WHICH MAY BE TREATED BY THE COMPANY, THE TRUSTEE AND ANY AGENT THEREOF AS OWNER AND HOLDER OF THIS NOTE FOR ALL PURPOSES.

UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY TO THE COMPANY OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF CEDE & CO. OR IN SUCH OTHER NAME AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY (AND ANY PAYMENT HEREON IS MADE TO CEDE & CO. OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY), ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL SINCE THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.

TRANSFERS OF THIS GLOBAL NOTE WILL BE LIMITED TO TRANSFERS IN WHOLE, BUT NOT IN PART, TO NOMINEES OF THE DEPOSITORY TRUST COMPANY, OR TO A SUCCESSOR THEREOF OR SUCH SUCCESSOR’S NOMINEE, AND TRANSFERS OF PORTIONS OF THIS GLOBAL NOTE WILL BE LIMITED TO TRANSFERS MADE IN ACCORDANCE WITH THE RESTRICTIONS SET FORTH IN ARTICLE 2 OF THE INDENTURE REFERRED TO ON THE REVERSE HEREOF.

[Include the following legend on all Notes unless such restrictions on Transfer are eliminated or otherwise waived by written consent of the Company:]

THE SECURITY EVIDENCED HEREBY HAS NOT BEEN REGISTERED UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), OR ANY STATE SECURITIES LAWS, AND, ACCORDINGLY, MAY NOT BE OFFERED OR SOLD EXCEPT AS SET FORTH IN THE FOLLOWING SENTENCE. BY ITS ACQUISITION HEREOF, THE HOLDER (1) AGREES THAT IT WILL NOT OFFER, RESELL, PLEDGE OR OTHERWISE TRANSFER THE SECURITY EVIDENCED HEREBY AT ANY TIME EXCEPT (A) TO THE COMPANY OR ANY SUBSIDIARY THEREOF, (B) FOR SO LONG AS THE SECURITY EVIDENCED HEREBY OR THE COMMON STOCK ISSUABLE UPON CONVERSION OF SUCH SECURITY IS ELIGIBLE FOR RESALE UNDER RULE 144A, TO A QUALIFIED INSTITUTIONAL BUYER IN COMPLIANCE WITH RULE 144A UNDER THE SECURITIES ACT, (C) PURSUANT TO A REGISTRATION STATEMENT THAT HAS BEEN DECLARED EFFECTIVE UNDER THE SECURITIES ACT (AND THAT CONTINUES TO BE EFFECTIVE AT THE TIME OF

 

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SUCH TRANSFER), (D) PURSUANT TO OFFERS AND SALES TO NON-U.S. PERSONS THAT OCCUR OUTSIDE THE UNITED STATES WITHIN THE MEANING OF REGULATION S UNDER THE SECURITIES ACT OR (E) PURSUANT TO ANOTHER AVAILABLE EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT, INCLUDING RULE 144 THEREUNDER (IF AVAILABLE); (2) PRIOR TO SUCH TRANSFER (OTHER THAN A TRANSFER PURSUANT TO CLAUSE 1(A) OR 1(C) ABOVE), AGREES TO FURNISH SUCH CERTIFICATIONS, LEGAL OPINIONS OR OTHER INFORMATION AS THE COMPANY, THE TRUSTEE OR THE TRANSFER AGENT, AS APPLICABLE, MAY REASONABLY REQUIRE TO CONFIRM THAT SUCH TRANSFER IS BEING MADE PURSUANT TO AN EXEMPTION FROM, OR IN A TRANSACTION NOT SUBJECT TO, THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT; AND (3) AGREES THAT IT WILL DELIVER TO EACH PERSON TO WHOM THIS SECURITY IS TRANSFERRED (OTHER THAN A TRANSFER PURSUANT TO CLAUSE 1(C) ABOVE) A NOTICE SUBSTANTIALLY TO THE EFFECT OF THIS LEGEND. BY ITS ACQUISITION HEREOF, THE HOLDER ALSO AGREES NOT TO ENGAGE IN ANY HEDGING TRANSACTIONS WITH RESPECT TO THE NOTES OR THE COMMON STOCK OF THE COMPANY UNLESS SUCH TRANSACTIONS ARE MADE IN ACCORDANCE WITH THE SECURITIES ACT.

 

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No.: [            ]

CUSIP: [            ]

ISIN:     [            ]

Principal Amount $[            ]

[as revised by the Schedule of Increases

and Decreases of Global Note attached hereto]2

Energy & Exploration Partners, Inc.

8.00% Convertible Subordinated Notes due 2019

Energy & Exploration Partners, Inc., a Delaware corporation, promises to pay to [            ],3 or

registered assigns, the principal amount of $[            ] [(as revised by the Schedule of Increases

and Decreases of Global Note attached hereto)]4 on July 1, 2019.

Interest Payment Dates: January 1 and July 1 of each year, beginning January 1, 2015.

Regular Record Dates: December 15 and June 15 of each year, beginning December 15, 2014.

Additional provisions of this Note are set forth on the other side of this Note.

 

2  Include for Global Notes only.
3  Insert Cede & Co. for Global Notes.
4  Include for Global Notes only.

 

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ENERGY & EXPLORATION PARTNERS, INC.
By:  

 

  Name:
  Title:
  Dated:

TRUSTEE’S CERTIFICATE OF AUTHENTICATION

U.S. BANK NATIONAL ASSOCIATION, as Trustee, certifies that this is one of the Notes referred to in the within-mentioned Indenture.

 

By:  

 

  Authorized Signatory
  Dated:

 

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[FORM OF REVERSE OF NOTE]

Energy & Exploration Partners, Inc.

8.00% Convertible Subordinated Notes due 2019

This Note is one of a duly authorized issue of notes of Energy & Exploration Partners, Inc., a Delaware corporation (the “Company”), designated as its 8.00% Convertible Subordinated Notes due 2019 (the “Notes”), all issued or to be issued under and pursuant to an indenture dated as of July 22, 2014 (the “Indenture”), among the Company and U.S. Bank National Association (the “Trustee”), to which Indenture and all indentures supplemental thereto reference is hereby made for a description of the rights, limitations of rights, obligations, duties and immunities thereunder of the Trustee, the Company and the Holders. Capitalized terms used herein and not defined herein have the meanings ascribed to them in the Indenture, and the terms of the Notes include those stated in the Indenture and those incorporated into the Indenture. Notwithstanding anything herein to the contrary, to the extent that any provision of this Note conflicts with the express provisions of the Indenture, the provisions of the Indenture will govern and control.

This Note will initially accrue interest at a rate equal to 8.00% per annum; provided that the Interest Rate on this Note will increase by 0.50% per annum on the Interest Payment Date falling on July 1, 2015 and on each Interest Payment Date thereafter in accordance with the provisions of the Indenture. Interest accruing on this Note will be payable entirely in cash.

If an Event of Default, as defined in the Indenture, shall have occurred and be continuing (other than an Event of Default relating to certain events of bankruptcy, insolvency or reorganization of the Company), the Terminal Value of all Notes may be declared, by either the Trustee or Holders of at least 25% in aggregate principal amount of Notes then outstanding, and upon said declaration shall become, due and payable, in the manner, with the effect and subject to the conditions and certain exceptions set forth in the Indenture. In case of certain events of bankruptcy, insolvency or reorganization of the Company as described above, the Terminal Value of the Notes will automatically become immediately due and payable.

Subject to the terms and conditions of the Indenture, the Company will make or cause to be made all payments and deliveries in respect of any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and accrued but unpaid interest on, as the case may be, to the Holder who surrenders this Note to a Paying Agent to collect such payments in respect of this Note. The Company will pay or cause to be paid all amounts in cash or by wire transfer of immediately available funds on the relevant payment date.

The Indenture contains provisions permitting the Company and the Trustee in certain circumstances, without the consent of the Holders, and in certain other circumstances, with the consent of the Holders of not less than a majority in aggregate principal amount of Notes at the time outstanding, evidenced as in the Indenture provided, to execute supplemental indentures modifying the terms of the Indenture and the Notes as described therein. It is also provided in the Indenture that, subject to certain exceptions, the Holders of a majority in aggregate principal amount of Notes at the time outstanding may on behalf of the Holders of all of the Notes waive any current or past Default or Event of Default under the Indenture and its consequences.

 

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Payment of principal, interest, penalties, fees, indemnifications, reimbursements, damages and other liabilities payable under the documentation governing any indebtedness due with respect to this Note is subordinated to the prior payment of Senior Debt on the terms provided in the Indenture.

No reference herein to the Indenture and no provision of this Note or of the Indenture shall alter or impair the obligations of the Company, which are absolute and unconditional, to pay any principal or Terminal Value of, Change of Control Repurchase Price or Redemption Price for, and interest on, this Note at the place, at the respective times, at the rate and in the lawful money herein prescribed.

The Notes are issuable in registered form without coupons in minimum denominations of $1,000.00 of principal amount and in integral multiples of $1,000 in excess thereof. A Holder may transfer or exchange Notes in accordance with the Indenture. The Registrar may require a Holder, among other things, to furnish appropriate endorsements and transfer documents and to pay any taxes and fees required by law or permitted by the Indenture. The Registrar need not transfer or exchange any Notes in respect of which a Change of Control Repurchase Notice has been given and not withdrawn after the Company has delivered a Redemption Notice (except to the extent that Notes are converted or the Company fails to pay the Redemption Price in accordance with the terms of the Indenture) or in respect of which a Conversion Notice has been given (except, in the case of a Note to be converted in part, the portion of the Note not to be converted).

No sinking fund is provided for the Notes. Subject to the terms and conditions of the Indenture, the Company may redeem all, but not less than all, of the Notes that are not subject to a Conversion Notice if the closing of a Qualified PO occurs. Additionally, on or following a Change of Control Repurchase Date, in the event that any Notes remain outstanding, the Company may redeem any such Notes, in whole but not in part. Any redemption will be at the Redemption Price and subject to the notice provisions set forth in the Indenture.

Subject to the terms and conditions of the Indenture, upon the occurrence of a Change of Control, the Holder of this Note will have the right, at its option, to require the Company to repurchase for cash this Note at the applicable Change of Control Repurchase Price set forth in the Indenture.

Subject to, and upon compliance with, the terms and conditions of the Indenture, the Holder of this Note may, at its option, convert all of this Note, or any portion of this Note, into Conversion Shares upon the closing of a Qualified PO.

In addition to the rights provided to Holders under the Indenture, Holders shall have all the rights set forth in the Registration Rights Agreement, dated as of July 22, 2014, among the Company and Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC/Sea Port Group Securities, LLC.

Initially, U.S. Bank National Association will act as the Trustee, Paying Agent, Conversion Agent and Registrar. The Company may appoint and change any Paying Agent, Conversion Agent or Registrar; provided, that the Company will maintain at least one Paying Agent, Conversion Agent and Registrar in the continental United States. The Company or any of the Subsidiaries may act as Paying Agent, Conversion Agent or Registrar.

 

A-7


The Holder of this Note will be treated as the owner of this Note for all purposes.

This Note will not be valid until an authorized signatory of the Trustee manually signs the Trustee’s certificate of authentication on the other side of this Note.

Customary abbreviations may be used in the name of a Holder or an assignee, such as TEN COM (=tenants in common), TEN ENT (=tenants by the entireties), JT TEN (=joint tenants with right of survivorship and not as tenants in common), CUST (=custodian), and U/G/M/A (=Uniform Gift to Minors Act).

THE INDENTURE AND THE NOTES WILL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF NEW YORK.

Pursuant to a recommendation promulgated by the Committee on Uniform Note Identification Procedures and the International Securities Identification Numbers Organization, the Company has caused CUSIP and ISIN numbers to be printed on the Notes, and the Trustee may use CUSIP and ISIN numbers in any notices as a convenience to Holders. No representation is made as to the accuracy of such numbers either as printed on the Notes or as contained in any notice, and reliance may be placed only on the other identification numbers placed thereon.

The Company will furnish to any Holder, upon written request and without charge, a copy of the Indenture which has in it the text of this Note. Requests may be made to:

Energy & Exploration Partners, Inc.

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, TX 76102

Telephone: (817) 315-9811

Attention: Legal Department

 

A-8


CONVERSION NOTICE

ENERGY & EXPLORATION PARTNERS, INC.

8.00% CONVERTIBLE SUBORDINATED NOTES DUE 2019

To convert this Note, check the box   ¨

To convert the entire principal amount of this Note, check the box   ¨

To convert only a portion of the principal amount of this Note, check the box ¨ and here specify the principal amount to be converted, which principal amount must equal $1,000 or an integral multiple of $1,000 in excess thereof:

$                        

The undersigned registered owner of this Note hereby represents and warrants that it, and any other Person in whose name the undersigned has requested Common Stock to be registered, is a “qualified institutional buyer” (as defined in Rule 144A under the Securities Act) or is an institution that, at the time the buy order for the Note was originated, was outside the United States and was not a U.S. person (and was not purchasing for the account or benefit of a U.S. person) within the meaning of Regulation S under the Securities Act, and it covenants and agrees that, during the Lock-up Period, the undersigned and its Affiliates will not:

(a) directly or indirectly sell or offer to sell any Conversion Shares or Related Securities (other than, for the avoidance of doubt, Conversion Shares covered by the registration statement for the Qualified PO) either Beneficially Owned or owned of record;

(b) enter into any swap, hedge or similar arrangement or agreement that transfers, in whole or in part, the economic risk of ownership of Conversion Shares or Related Securities (other than, for the avoidance of doubt, Conversion Shares covered by the registration statement for the Qualified PO), regardless of whether any such transaction is to be settled in securities, in cash or otherwise; or

(c) publicly announce any intention to do any of the foregoing.

As used herein, the term “Beneficially Owned” has a corresponding meaning to the meaning assigned to the term “Beneficial Owner” in Rule 13d-3 and Rule 13d-5 under the Exchange Act, except that in calculating the beneficial ownership of any particular “person” (as that term is used in Section 13(d)(3) of the Exchange Act), such “person” will be deemed to have beneficial ownership of all securities that such “person” has the right to acquire by conversion or exercise of other securities, whether such right is currently exercisable or is exercisable only after the passage of time.

Capitalized terms used herein and not defined herein have the meanings ascribed to them in the Indenture

 

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[Signature Page Follows]

 

Signature Guaranteed

 

Participant in a Recognized Signature
Guarantee Medallion Program
By:  

 

  Authorized Signatory

Signature Page – Conversion Notice

 

A-10


CHANGE OF CONTROL REPURCHASE NOTICE

U.S. Bank National Association

13737 Noel Road, Suite 800

Dallas, Texas 75240

Attention: Corporate Trust Services

The undersigned registered owner of this Note hereby acknowledges receipt of a notice from Energy & Exploration Partners, Inc. (the “Company”) as to the occurrence of a Change of Control with respect to the Company and specifying the Change of Control Repurchase Date and requests and instructs the Company to pay to the Holder hereof in accordance with the applicable provisions of the Indenture referred to in this Note (1) the entire principal amount of this Note, or the portion thereof (that is equal to $1,000 principal amount or an integral multiple of $1,000 in excess thereof) below designated, and (2) if such Change of Control Repurchase Date does not occur during the period after a Regular Record Date and on or prior to the corresponding Interest Payment Date, accrued and unpaid interest, if any, thereon to, but excluding, such Change of Control Repurchase Date.

Principal amount to be repaid (if less than all): $                    

Signature Guaranteed

 

 

Participant in a Recognized Signature
Guarantee Medallion Program
By:  

 

Authorized Signatory

 

A-11


CERTIFICATE TO BE DELIVERED UPON EXCHANGE OR TRANSFER OF NOTES

Energy & Exploration Partners, Inc.

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, Texas 76102

Telephone: (817) 315-9811

Attention: Legal Department

U.S. Bank National Association

13737 Noel Road, Suite 800

Dallas, Texas 75240

Attention: Corporate Trust Services

Re: CUSIP #

Reference is hereby made to that certain Indenture, dated July 22, 2014 (the “Indenture”) among Energy & Exploration Partners, Inc. (the “Company”) and U.S. Bank National Association, as trustee (the “Trustee”). Capitalized terms used but not defined herein shall have the meanings set forth in the Indenture.

This certificate relates to $[            ] principal amount of Notes held in (check applicable space) ¨ book-entry or ¨ definitive form by the undersigned.

The undersigned                     (transferor) (check one box below):

¨  hereby requests the Registrar to deliver in exchange for its beneficial interest in the Global Note held by the Depositary a Note or Notes in definitive, registered form of authorized denominations and an aggregate principal amount equal to its beneficial interest in such Global Note (or the portion thereof indicated above), in accordance with Section 2.09 of the Indenture; or

¨  hereby requests the Trustee to exchange a Note or Notes to (transferee).

In connection with any transfer of any of the Notes evidenced by this certificate, the undersigned confirms that such Notes are being transferred in accordance with its terms:

¨  (1) to the Company or any of its subsidiaries; or

¨  (2) to a “qualified institutional buyer” (as defined in Rule 144A under the Securities Act) that purchases for its own account or for the account of a qualified institutional buyer to whom notice is given that such transfer is being made in reliance on Rule 144A under the Securities Act, in each case pursuant to and in compliance with Rule 144A thereunder;

¨  (3) pursuant to and in accordance with Regulation S under the Securities Act to an institution that, at the time the buy order was originated, was outside the United States and was not a U.S. person (and was not purchasing for the account or benefit of a U.S. person);

 

A-12


¨  (4) pursuant to Rule 144 under the Securities Act;

¨  (5) pursuant to and in compliance with an exemption from the registration requirements of the Securities Act other than Rule 144A, Rule 144 or Regulation S; or

¨  (6) pursuant to an effective registration statement under the Securities Act.

Unless one of the boxes is checked, the Registrar will refuse to register any of the Notes evidenced by this certificate in the name of any person other than the registered holder thereof.

 

Signature Guaranteed

 

Participant in a Recognized Signature
Guarantee Medallion Program
By:  

 

Authorized Signatory

 

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[Include for Global Note]

SCHEDULE OF INCREASES AND DECREASES OF GLOBAL NOTE

Initial Principal Amount of Global Note: $[            ]

 

Date

   Amount of Increase
in Principal
Amount of Global
Note
   Amount of
Decrease in
Principal Amount
of Global Note
   Principal Amount
of Global Note
After Increase or
Decrease
   Notation by
Registrar or Note
Custodian
           
           
           
           
           
           
           
           
           
           
           
           
           
           
           
           
           
           

 

A-14


EXHIBIT B

[FORM OF RESTRICTED STOCK LEGEND]

[Each certificate representing Conversion Shares will bear the following legend unless it has been sold pursuant to a registration statement that has been declared effective under the Securities Act:]

THE SECURITY EVIDENCED HEREBY HAS NOT BEEN REGISTERED UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), OR ANY STATE SECURITIES LAWS, AND, ACCORDINGLY, MAY NOT BE OFFERED OR SOLD EXCEPT AS SET FORTH IN THE FOLLOWING SENTENCE. BY ITS ACQUISITION HEREOF, THE HOLDER (1) AGREES THAT IT WILL NOT OFFER, RESELL, PLEDGE OR OTHERWISE TRANSFER THE SECURITY EVIDENCED HEREBY AT ANY TIME EXCEPT (A) TO THE COMPANY OR ANY SUBSIDIARY THEREOF, (B) FOR SO LONG AS THE SECURITY EVIDENCED HEREBY OR THE COMMON STOCK ISSUABLE UPON CONVERSION OF SUCH SECURITY IS ELIGIBLE FOR RESALE UNDER RULE 144A, TO A QUALIFIED INSTITUTIONAL BUYER IN COMPLIANCE WITH RULE 144A UNDER THE SECURITIES ACT, (C) PURSUANT TO A REGISTRATION STATEMENT THAT HAS BEEN DECLARED EFFECTIVE UNDER THE SECURITIES ACT (AND THAT CONTINUES TO BE EFFECTIVE AT THE TIME OF SUCH TRANSFER), (D) PURSUANT TO OFFERS AND SALES TO NON-U.S. PERSONS THAT OCCUR OUTSIDE THE UNITED STATES WITHIN THE MEANING OF REGULATION S UNDER THE SECURITIES ACT OR (E) PURSUANT TO ANOTHER AVAILABLE EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT, INCLUDING RULE 144 THEREUNDER (IF AVAILABLE); (2) PRIOR TO SUCH TRANSFER (OTHER THAN A TRANSFER PURSUANT TO CLAUSE 1(A) OR 1(C) ABOVE), AGREES TO FURNISH SUCH CERTIFICATIONS, LEGAL OPINIONS OR OTHER INFORMATION AS THE COMPANY, THE TRUSTEE OR THE TRANSFER AGENT, AS APPLICABLE, MAY REASONABLY REQUIRE TO CONFIRM THAT SUCH TRANSFER IS BEING MADE PURSUANT TO AN EXEMPTION FROM, OR IN A TRANSACTION NOT SUBJECT TO, THE REGISTRATION REQUIREMENTS OF THE SECURITIES ACT; AND (3) AGREES THAT IT WILL DELIVER TO EACH PERSON TO WHOM THIS SECURITY IS TRANSFERRED (OTHER THAN A TRANSFER PURSUANT TO CLAUSE 1(C) ABOVE) A NOTICE SUBSTANTIALLY TO THE EFFECT OF THIS LEGEND. BY ITS ACQUISITION HEREOF, THE HOLDER ALSO AGREES NOT TO ENGAGE IN ANY HEDGING TRANSACTIONS WITH RESPECT TO THE NOTES OR THE COMMON STOCK OF THE COMPANY UNLESS SUCH TRANSACTIONS ARE MADE IN ACCORDANCE WITH THE SECURITIES ACT.

 

B-1



Exhibit 4.2

Execution Copy

$375,000,000

ENERGY & EXPLORATION PARTNERS, INC.

8.0% Convertible Subordinated Notes due 2019

REGISTRATION RIGHTS AGREEMENT

July 22, 2014

Citigroup Global Markets Inc.

Credit Suisse Securities (USA) LLC

Global Hunter Securities, LLC/Sea Port Group Securities, LLC

As Representatives of the Initial Purchasers

c/o Citigroup Global Markets Inc.

388 Greenwich Street

New York, New York 10013

Ladies and Gentlemen:

Energy & Exploration Partners, Inc., a Delaware corporation (the “Company”), is issuing and selling to Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC (together with its affiliate Sea Port Group Securities, LLC) (the “Initial Purchasers”), upon the terms set forth in the Purchase Agreement, dated July 10, 2014, by and among the Company and the Initial Purchasers (the “Purchase Agreement”), $375,000,000 aggregate principal amount of the Company’s 8.0% Convertible Subordinated Notes due 2019 (the “Notes”). The Notes will be convertible into shares of common stock of the Company (the “Conversion Shares”).

As an inducement to the Initial Purchasers to enter into the Purchase Agreement, the Company agrees with the Initial Purchasers, for the benefit of the holders from time to time of the Securities (including, if applicable, the Initial Purchasers) (each a “Holder” and, collectively, the “Holders”), as follows:

 

1. Definitions

As used in this Agreement, the following terms shall have the following meanings:

Adverse Effect: See Section 2(b) hereof.

Agreement: This Registration Rights Agreement, dated as of the Closing Date, among the Company and the Initial Purchasers.

Business Day: A day that is not a Saturday, a Sunday or a day on which banking institutions in the City of New York are authorized or required by law or executive order to be closed.


Closing Date: July 22, 2014.

Common Stock: See Section 2(a) hereof.

Company: The party named as such in the first paragraph of this Agreement until a successor or assignee replaces it pursuant to the applicable provisions hereof and, thereafter, means the successor or assignee.

Conversion Shares: See the introductory paragraphs to this Agreement.

day: Unless otherwise expressly provided, a calendar day.

Deferral Period: See Section 4(q) hereof.

Effectiveness Date: The 180th day after the closing of a Qualified PO.

Effectiveness Period: See Section 3(a) hereof.

Exchange Act: The Securities Exchange Act of 1934, as amended, and the rules and regulations of the SEC promulgated thereunder.

FINRA: Financial Industry Regulatory Authority, Inc.

Holder: See the introductory paragraphs to this Agreement.

Holders’ Counsel: See Section 4(a) hereof.

Indemnified Party: See Section 6(c) hereof.

Indemnifying Party: See Section 6(c) hereof.

Indenture: The Indenture, dated as of the Closing Date, among the Company and U.S Bank National Association, as trustee, pursuant to which the Notes are being issued, as amended or supplemented from time to time in accordance with the terms thereof.

Initial Purchasers: See the introductory paragraphs to this Agreement.

Initial Resale Registration Statement: See Section 3(a) hereof.

Inspectors: See Section 4(k) hereof.

Losses: See Section 6(a) hereof.

Managing Underwriters: With respect to any Underwritten Offering, the book-running lead manager or managers of such Underwritten Offering.

Maximum Contribution Amount: See Section 6(d) hereof.

Notes: See the introductory paragraphs to this Agreement.

 

2


Notice and Questionnaire: See Section 4(p) hereof.

Notice Holder: On any date, any Holder that has delivered a Notice and Questionnaire to the Company on or prior to such date.

Person: An individual, trustee, corporation, partnership, limited liability company, joint stock company, trust, unincorporated association, union, business association, firm, government or agency or political subdivision thereof, or other legal entity.

Piggyback Notice: See Section 2(a) hereof.

Piggyback Registration Statement: See Section 2(a) hereof.

Prospectus: The prospectus included in any Registration Statement (including, without limitation, a prospectus that discloses information previously omitted from a prospectus filed as part of an effective registration statement in reliance upon Rule 430A promulgated under the Securities Act), as amended or supplemented by any prospectus supplement, with respect to the terms of the offering of any portion of the Registrable Securities covered by such Registration Statement, and all other amendments and supplements to the Prospectus, including post-effective amendments, and all material incorporated by reference or deemed to be incorporated by reference in such Prospectus.

Purchase Agreement: See the introductory paragraphs to this Agreement.

Qualified PO: Has the meaning provided in the Indenture.

Qualified PO Filing Date: Has the meaning provided in the Indenture.

Records: See Section 4(k) hereof.

Registrable Securities: All outstanding Conversion Shares held by any Holder and all securities issued or issuable with respect to such Conversion Shares as a result of any stock split, stock dividend, recapitalization, exchange or similar event; provided, however, that such securities shall cease to be Registrable Securities upon the earliest to occur of the following: (i) such securities have been sold pursuant to an effective Registration Statement or (ii) such securities either (x) have been sold pursuant to Rule 144 or (y) are eligible to be sold pursuant to Rule 144 (with any legend restricting transfer of such securities having been removed (whether such security is evidence in global or certificated form) and an unrestricted CUSIP number having been assigned to such security), in each case by a Person who is not, and has not been for the three months preceding the proposed sale date, an affiliate (as defined in Rule 144) of the Company.

Registration Statement: Any registration statement of the Company filed with the SEC under the Securities Act (including, but not limited to, the Piggyback Registration Statement, the Initial Resale Registration Statement and any Subsequent Resale Registration Statement) that covers any of the Registrable Securities pursuant to the provisions of this Agreement, including the Prospectus, amendments and supplements to such registration statement, including post-effective amendments, all exhibits and all material incorporated by reference or deemed to be incorporated by reference in such registration statement.

 

3


Resale Registration Statement: See Section 3(b) hereof.

Rule 144: Rule 144 promulgated under the Securities Act, as such Rule may be amended from time to time, or any similar rule (other than Rule 144A) or regulation hereafter adopted by the SEC.

Rule 144A: Rule 144A promulgated under the Securities Act, as such Rule may be amended from time to time, or any similar rule (other than Rule 144) or regulation hereafter adopted by the SEC.

Rule 415: Rule 415 promulgated under the Securities Act, as such Rule may be amended from time to time, or any similar rule or regulation hereafter adopted by the SEC.

Rule 430A: Rule 430A promulgated under the Securities Act, as such Rule may be amended from time to time, or any similar rule or regulation hereafter adopted by the SEC.

SEC: The Securities and Exchange Commission.

Securities: The Notes and the Conversion Shares.

Securities Act: The Securities Act of 1933, as amended, and the rules and regulations of the SEC promulgated thereunder.

Specified Post-Effective Amendment: A post-effective amendment to a Resale Registration Statement on Form S-1 (i) required in connection with the Company’s Annual Report on Form 10-K or any amendment thereto or (ii) filed to convert such Resale Registration Statement into a Registration Statement on Form S-3.

Subsequent Resale Registration Statement: See Section 3(b) hereof.

Trustee: The trustee under the Indenture.

Underwriter: Any underwriter in an Underwritten Registration or Underwritten Offering.

Underwritten Registration or Underwritten Offering: A registration in which securities of the Company are sold to an underwriter for reoffering to the public.

 

2. Piggyback Registration Rights

(a) Participation. If the Company proposes to file, whether for its own account or for the account of the Holders, any registration statement in connection with the sale of shares of its common stock (“Common Stock”) in a Qualified PO (a “Piggyback Registration Statement”), then the Company shall give written notice (a “Piggyback Notice”) to each Holder regarding such proposed registration, and such notice shall offer such Holders a reasonable opportunity to

 

4


include in such Piggyback Registration Statement, prior to the effectiveness of such Piggyback Registration Statement, such number of Registrable Securities as each such Holder may request, subject to the limitations set forth in this paragraph. Each Piggyback Notice shall specify the number of shares of Common Stock proposed to be registered, an indication of the expected timing of the Qualified PO, the proposed means of distribution and the proposed Managing Underwriters (if any and if known) and shall be accompanied by a Notice and Questionnaire. Each such Holder (a “Participating Holder”) shall make such request in writing to the Company within ten (10) days after the receipt of any such Piggyback Notice, which request shall specify the number of Registrable Securities intended to be disposed of by such Holder (which may be expressed as a percentage of the Registrable Securities such Holder will possess on the Conversion Date upon the conversion of such Holder’s Notes into Conversion Shares in accordance with and pursuant to the Indenture) (such number of shares, the “Participation Amount”) and shall be accompanied by a fully completed and executed Notice and Questionnaire, and, subject to the terms and conditions of this Agreement, the Company shall use its reasonable best efforts to include in such Piggyback Registration Statement all such Registrable Securities held by such Holders; provided, that if, at any time after giving written notice of its intention to register Common Stock and prior to the effective date of the registration statement filed in connection with such registration, the Company shall determine for any reason not to register such Common Stock, the Company may, at its election, give written notice of such determination within five Business Days thereof to each Holder of Registrable Securities and, thereupon, shall not be obligated to register any Registrable Securities in connection with such registration (but shall nevertheless pay the registration expenses set forth in Section 5 in connection therewith), without prejudice, however, to the rights of the Holders of Registrable Securities that a registration be effected under Section 3 hereof; provided further, that, subject to the immediately preceding proviso, the aggregate number of Conversion Shares to be sold in the Qualified PO by each Participating Holder shall not exceed 36% (the “Participation Limit”) of the total number of Conversion Shares held by such Participating Holder.

(b) Cut Back. If in connection with an Underwritten Offering pursuant to this Section 2, the Managing Underwriter shall advise the Company that, in its reasonable opinion, the number of securities requested and otherwise proposed to be included in such Underwritten Offering exceeds the number which can be sold in such offering without an adverse effect on the price, timing or distribution of the Common Stock to be offered (an “Adverse Effect”), then in the case of any such Piggyback Registration Statement pursuant to this Section 2, the Company shall include in such Piggyback Registration Statement the number of Registrable Securities that such Managing Underwriter advises the Company can be sold without having such Adverse Effect.

 

3. Resale Registration

(a) Initial Resale Registration. Following the consummation of a Qualified PO, the Company shall file with the SEC a Registration Statement for an offering to be made on a continuous basis pursuant to Rule 415 covering all of the Registrable Securities (the “Initial Resale Registration Statement”). The Company shall use its reasonable best efforts to cause such Initial Resale Registration Statement to be declared effective under the Securities Act on or prior to the Effectiveness Date. The Initial Resale Registration Statement shall be on Form S-1 or another appropriate form permitting registration of such Registrable Securities for resale by

 

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Holders in the manner or manners reasonably designated by them (including, without limitation, one or more Underwritten Offerings). The Company shall use its reasonable best efforts to keep the Initial Resale Registration Statement continuously effective under the Securities Act until there are no Registrable Securities outstanding (the “Effectiveness Period”) or a Subsequent Resale Registration Statement covering all of the Registrable Securities covered by and not sold under the Initial Resale Registration Statement or an earlier Subsequent Resale Registration Statement has been declared effective under the Securities Act.

(b) Subsequent Resale Registrations. If the Initial Resale Registration Statement or any Subsequent Resale Registration Statement (as defined below) ceases to be effective for any reason at any time during the Effectiveness Period (other than because of the sale of all of the securities registered thereunder), the Company shall use its reasonable best efforts to obtain the prompt withdrawal of any order suspending the effectiveness thereof, and in any event shall within 30 days of such cessation of effectiveness amend such Resale Registration Statement in a manner to obtain the withdrawal of the order suspending the effectiveness thereof, or file an additional “shelf” Registration Statement pursuant to Rule 415 covering all of the Registrable Securities (a “Subsequent Resale Registration Statement”). If a Subsequent Resale Registration Statement is filed, the Company shall use its reasonable best efforts to cause the Subsequent Resale Registration Statement to be declared effective as soon as practicable after such filing and to keep such Subsequent Resale Registration Statement continuously effective for the remainder of the Effectiveness Period. As used herein the term “Resale Registration Statement” means the Initial Resale Registration Statement and any Subsequent Resale Registration Statements.

(c) Supplements and Amendments. The Company shall promptly supplement and amend any Resale Registration Statement if required by the rules, regulations or instructions applicable to the registration form used for such Resale Registration Statement, if required by the Securities Act.

 

4. Registration Procedures

In connection with the filing of any Registration Statement pursuant to Section 2 or 3 hereof, the Company shall effect such registrations to permit the sale of such securities covered thereby in accordance with the intended method or methods of disposition thereof, and pursuant thereto and in connection with any Registration Statement filed by the Company hereunder, the Company shall:

(a) If (1) a Resale Registration Statement is filed pursuant to Section 3 hereof or (2) a Prospectus contained in a Registration Statement filed pursuant to Section 2 hereof is required to be delivered under the Securities Act by any Underwriter, before filing any Registration Statement or Prospectus or any amendments or supplements thereto the Company shall, if requested, furnish to and afford the Holders of the Registrable Securities to be registered pursuant to such Resale Registration Statement, the Managing Underwriter, if any, and each of their respective counsel, a reasonable opportunity to review copies of all such documents (including copies of any documents to be incorporated by reference therein and all exhibits thereto) proposed to be filed (in each case at least 5 Business Days prior to such filing). The Company shall not file any such Registration Statement or Prospectus or any amendments or supplements thereto in respect of which the Holders must provide information for the inclusion therein without

 

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the Holders being afforded an opportunity to review such documentation if the Holders of a majority of the Registrable Securities covered by such Registration Statement, or any Managing Underwriter, if any, or one counsel selected by the Holders of a majority of the Registrable Securities covered by such Registration Statement (“Holders’ Counsel”) shall reasonably object in writing within three (3) Business Days of receipt of such Registration Statement or Prospectus or any amendments or supplements.

(b) Use its reasonable best efforts to prepare and file with the SEC such pre-effective amendments and post-effective amendments to each Resale Registration Statement as may be necessary to keep such Registration Statement continuously effective for the Effectiveness Period, cause any Prospectus to be supplemented by any Prospectus supplement required by applicable law, and to be filed pursuant to Rule 424 (or any similar provisions then in force) promulgated under the Securities Act; and comply with the provisions of the Securities Act and the Exchange Act applicable to them with respect to the disposition of all securities covered by such Registration Statement as so amended or in such Prospectus as supplemented.

(c) Furnish to such selling Holders and Managing Underwriters who so request in writing (i) such reasonable number of copies of such Registration Statement and of each amendment and supplement thereto (in each case including any documents incorporated therein by reference and all exhibits), (ii) such reasonable number of copies of the Prospectus included in such Registration Statement (including each preliminary Prospectus) and each amendment and supplement thereto, and such reasonable number of copies of the final Prospectus as filed by the Company pursuant to Rule 424(b) under the Securities Act, in conformity with the requirements of the Securities Act and each amendment and supplement thereto, and (iii) such other documents (including any amendments required to be filed pursuant to Section 4(b) hereof), as any such Person may reasonably request in writing. Subject to Section 3(q) hereof, the Company hereby consents to the use of the Prospectus in accordance with applicable law by each of the selling Holders of Registrable Securities or each Underwriter, as the case may be, and the underwriters or agents, if any, and dealers, if any, in connection with the offering and sale of the Registrable Securities in accordance with applicable law covered by, or the sale by the Underwriters pursuant to, such Prospectus and any amendment or supplement thereto.

(d) If (1) a Resale Registration Statement is filed pursuant to Section 3 hereof, or (2) a Prospectus contained in a Registration Statement filed pursuant to Section 2 hereof is required to be delivered under the Securities Act by any Underwriter, the Company shall notify in writing the selling Holders of Registrable Securities and the Managing Underwriter, if any, and each of their respective counsel promptly (but in any event within two Business Days) (i) when a Prospectus or any Prospectus supplement or post-effective amendment has been filed, and, with respect to a Registration Statement or any post-effective amendment, when the same has become effective (including in such notice a written statement that any Holder may, upon request, obtain, without charge, one conformed copy of such Registration Statement or post-effective amendment including financial statements and schedules, documents incorporated or deemed to be incorporated by reference and exhibits), (ii) of the issuance by the SEC of any stop order suspending the effectiveness of a Registration Statement or of any order preventing or suspending the use of any Prospectus or the initiation of any proceedings for that purpose, (iii) if, between the applicable effective date of a Resale Registration Statement and the closing of any sale of Registrable Securities covered thereby, the representations and warranties of the Company

 

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contained in any underwriting agreement, securities sales agreement or other similar agreement, if any, relating to an offering of such Registrable Securities cease to be true and correct in all material respects, (iv) of the receipt by the Company of any notification with respect to the suspension of the qualification or exemption from qualification of a Registration Statement or any of the Registrable Securities for offer or sale in any jurisdiction, or the initiation of any proceeding for such purpose, (v) of the happening of any event, the existence of any condition of any information becoming known that makes any statement made in such Registration Statement or related Prospectus or any document incorporated or deemed to be incorporated therein by reference untrue in any material respect or that requires the making of any changes in, or amendments or supplements to, such Registration Statement, Prospectus or documents so that, in the case of the Registration Statement and the Prospectus, it will not contain any untrue statement of a material fact or omit to state any material fact required to be stated therein or necessary to make the statements therein, in light of the circumstances under which they were made, not misleading, (vi) of any reasonable determination by the Company that a post-effective amendment to a Registration Statement would be appropriate and (vii) of any request by the SEC for amendments to the Registration Statement or supplements to the Prospectus or for additional information relating thereto.

(e) Use its reasonable best efforts to prevent the issuance of any order suspending the effectiveness of a Registration Statement or of any order preventing or suspending the use of a Prospectus or suspending the qualification (or exemption from qualification) of any of the Registrable Securities, for sale in any jurisdiction, and, if any such order is issued, to use its reasonable best efforts to obtain the withdrawal of any such order at the earliest possible date.

(f) If (A) a Resale Registration Statement is filed pursuant to Section 3 hereof, (B) a Prospectus contained in an Registration Statement filed pursuant to Section 2 hereof is required to be delivered under the Securities Act by any Participating Underwriter or (C) reasonably requested in writing by the Managing Underwriters, if any, or the Holders of a majority in aggregate principal amount of the Registrable Securities being sold in connection with an Underwritten Offering or Holders’ Counsel, (i) promptly incorporate in a Prospectus supplement or post-effective amendment such information or revisions to information therein relating to such Underwriters or selling Holders as the Managing Underwriters, if any, or such Holders or Holders’ Counsel reasonably request in writing to be included or made therein and (ii) make all required filings of such Prospectus supplement or such post-effective amendment as soon as reasonably practicable after the Company has received notification of the matters to be incorporated in such Prospectus supplements or post-effective amendment; provided that the Company shall not have any obligation to incorporate any information or revisions if the Company expects that so doing would cause such Prospectus supplement or post-effective amendment to contain an untrue statement of a material fact or omit to state any material fact necessary to make the statements therein not misleading or fail to comply with the applicable requirements of the Securities Act.

(g) Prior to any public offering of Registrable Securities or any delivery of a Prospectus by any Underwriter, use its reasonable best efforts to register or qualify, and to cooperate with the selling Holders of Registrable Securities or the Managing Underwriters, as the case may be, and their respective counsel in connection with the registration or qualification (or exemption from such registration or qualification) of such Registrable Securities, for offer and

 

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sale under the securities or Blue Sky laws of such jurisdictions within the United States as any selling Holder, Underwriter or the Managing Underwriters, if any, reasonably request in writing; provided, that where Registrable Securities are offered other than through an Underwritten Offering, the Company agrees to use reasonable best efforts to cause its counsel to perform Blue Sky investigations and file any registrations and qualifications required to be filed pursuant to this Section 4(g), keep each such registration or qualification (or exemption therefrom) effective during the period such Registration Statement is required to be kept effective and do any and all other acts or things reasonably necessary or advisable to enable the disposition in such jurisdictions of the Registrable Securities covered by the applicable Registration Statement; provided that the Company shall not be required to (A) qualify to do business or as a broker or dealer in securities in any jurisdiction where it is not then so qualified, (B) take any action that would subject it to general service of process in any such jurisdiction where it is not then so subject or (C) subject itself to taxation in any such jurisdiction where it is not then so subject.

(h) Use its reasonable best efforts to cause the Registrable Securities covered by any Registration Statement to be registered with or approved by such U.S. governmental agencies or authorities as may be necessary to enable the seller or sellers thereof or the underwriter, if any, to consummate the disposition of such Registrable Securities, except as may be required solely as a consequence of the nature of such selling Holder’s business, in which case the Company shall cooperate in all reasonable respects with the filing of such Registration Statement and the granting of such approvals; provided that the Company shall not be required to (A) qualify to do business or as a broker or dealer in securities in any jurisdiction where it is not then so qualified, (B) take any action that would subject it to general service of process in any such jurisdiction where it is not then so subject or (C) subject itself to taxation in any such jurisdiction where it is not then so subject.

(i) If (1) a Resale Registration Statement is filed pursuant to Section 3 hereof, or (2) a Prospectus pertaining to a Registration Statement filed pursuant to Section 2 hereof is required to be delivered under the Securities Act by any Underwriter, upon the occurrence of any event contemplated by clause (v) or (vi) of Section 4(d) hereof, as promptly as practicable, prepare and file with the SEC, at the expense of the Company, a supplement or post-effective amendment to the Registration Statement or a supplement to the related Prospectus or any document incorporated or deemed to be incorporated therein by reference, or file any other required document so that, as thereafter delivered to the purchasers of the Registrable Securities being sold thereunder or to the purchasers of the Registrable Securities to whom such Prospectus will be delivered by a Underwriter, such Prospectus will not contain an untrue statement of a material fact or omit to state a material fact required to be stated therein or necessary to make the statements therein, in light of the circumstances under which they were made, not misleading, and, if SEC review is required, use its reasonable best efforts to cause such post-effective amendment to be declared effective as soon as possible.

(j) If a Registration Statement is filed pursuant to Section 2 or 3 hereof, enter into such agreements (including an underwriting agreement in form, scope and substance as is customary in underwritten offerings of equity securities similar to the Conversion Shares, as may be appropriate in the circumstances) and take all such other actions in connection therewith (including those reasonably requested in writing by the Managing Underwriters, if any, or the Holders of a majority of the Registrable Securities being sold or Holders’ Counsel) in order to

 

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expedite or facilitate the registration or the disposition of such Registrable Securities, and in such connection, whether or not an underwriting agreement is entered into and whether or not the registration is an Underwritten Registration, (i) make such representations and warranties to the Holders of Registrable Securities and the Underwriters, if any, with respect to the business of the Company and its subsidiaries as then conducted, and the Registration Statement, Prospectus and documents, if any, incorporated or deemed to be incorporated by reference therein, in each case, in form, substance and scope as are customarily made by issuers to underwriters in underwritten offerings of equity securities similar to the Common Stock, as may be appropriate in the circumstances, and confirm the same if and when reasonably required; (ii) obtain an opinion of counsel to the Company and updates thereof (which counsel and opinions (in form, scope and substance) shall be reasonably satisfactory to the Managing Underwriters, if any), addressed to each selling Holder and each of the Managing Underwriters, if any, covering the matters customarily covered in opinions of counsel to the issuers requested in underwritten offerings of equity securities similar to the Common Stock, as may be appropriate in the circumstances; (iii) obtain “comfort” letters and updates thereof (which letters and updates (in form, scope and substance) shall be reasonably satisfactory to the Managing Underwriters) from the independent certified public accountants of the Company (and, if necessary, any other independent certified public accountants of any subsidiary of the Company or of any business acquired by the Company for which financial statements and financial data are, or are required to be, included in the Registration Statement), addressed to each of the Managing Underwriters, such letters to be in customary form and covering matters of the type customarily covered in “comfort” letters in connection with underwritten offerings of equity securities similar to the Common Stock, as may be appropriate in the circumstances, and such other matters as reasonably requested in writing by the Managing Underwriters; and (iv) deliver such documents and certificates as may be reasonably requested in writing by the Holders of a majority in aggregate principal amount of the Registrable Securities being sold and the Managing Underwriters, if any, or Holders’ Counsel to evidence the continued validity of the representations and warranties of the Company and its subsidiaries made pursuant to clause (i) above and to evidence compliance with any conditions contained in the underwriting agreement or other similar agreement entered into by the Company.

(k) If (1) a Resale Registration Statement is filed pursuant to Section 3 hereof, or (2) a Prospectus contained in an Registration Statement filed pursuant to Section 2 hereof is required to be delivered under the Securities Act by any Underwriter, make available for inspection by any selling Holder of such Registrable Securities being sold, or the Managing Underwriters, if any, as the case may be, and any attorney, accountant or other agent retained by any such selling Holder or the Managing Underwriters, as the case may be (collectively, the “Inspectors”), electronically or at the offices where normally kept, during reasonable business hours and in a reasonable manner, all financial and other records and pertinent corporate documents of the Company and its subsidiaries (collectively, the “Records”) as shall be reasonably necessary to enable them to exercise any applicable due diligence responsibilities, and cause the officers, directors and employees of the Company and its subsidiaries to supply all information reasonably requested in writing by any such Inspector in connection with such Registration Statement. Each Inspector shall agree in writing that it will keep the Records confidential and not disclose any of the Records unless (i) the disclosure of such Records is necessary to avoid or correct a misstatement or omission in such Registration Statement, (ii) the release of such Records is ordered pursuant to a subpoena or other order from a court of competent jurisdiction, (iii) the information in such Records is public or has been made generally available to the public other than as a result of a

 

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disclosure or failure to safeguard by such Inspector or (iv) disclosure of such information is, in the reasonable written opinion of counsel for any Inspector, necessary or advisable in connection with any action, claim, suit or proceeding, directly or indirectly, involving or potentially involving such Inspector and arising out of, based upon, related to, or involving this Agreement, or any transaction contemplated hereby or arising hereunder. Each selling Holder of such Registrable Securities and each Managing Underwriter will be required to agree that information obtained by it as a result of such inspections shall be deemed confidential and shall not be used by it as the basis for any market transactions in the securities of the Company unless and until such is made generally available to the public. Each Inspector, each selling Holder of such Registrable Securities and the Managing Underwriters will be required to further agree that it will, upon learning that disclosure of such Records is sought in a court of competent jurisdiction, give notice to the Company and, to the extent practicable, use its reasonable best efforts to allow the Company, at its expense, to undertake appropriate action to prevent disclosure of the Records deemed confidential.

(l) Use its reasonable best efforts to comply with all applicable rules and regulations of the SEC and make generally available to the security holders of the Company with regard to any applicable Registration Statement earning statements satisfying the provisions of Section 11(a) of the Securities Act and Rule 158 thereunder (or any similar rule promulgated under the Securities Act) no later than 45 days after the end of any 12-month period (or 90 days after the end of any 12-month period if such period is a fiscal year) (i) commencing at the end of any fiscal quarter in which Registrable Securities are sold to Underwriters in a firm commitment or best efforts Underwritten Offering and (ii) if not sold to Underwriters in such an offering, commencing on the first day of the first fiscal quarter of the Company after the effective date of a Registration Statement, which statements shall cover said 12-month periods.

(m) Cooperate with each seller of Registrable Securities covered by any Registration Statement and the Managing Underwriters, if any, participating in the disposition of such Registrable Securities and their respective counsel in connection with any filings required to be made with FINRA.

(n) Use its reasonable best efforts to cause all Registrable Securities covered by a Registration Statement to be listed on each securities exchange, if any, on which similar equity securities issued by the Company are then listed.

(o) Use its reasonable best efforts to take all other steps reasonably necessary to effect the registration of the Registrable Securities covered by a Registration Statement contemplated hereby.

(p) The Company may require each seller of Registrable Securities as to which any registration is being effected to furnish to the Company such information regarding such seller and the Registrable Securities being offered by such seller or as the Company may, from time to time, reasonably request in writing. The Company may exclude from such registration the Registrable Securities of any seller who fails to furnish such information within a reasonable time after receiving such request. Each seller of Registrable Securities as to which any registration is being effected agrees, by acquisition of such Registrable Securities, to furnish promptly to the Company all information required to be disclosed in order to make the information previously

 

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furnished by such seller not materially misleading. Subject to applicable law, the Company shall provide written notice to the Holders of the Registrable Securities, including a notice and questionnaire substantially in the form of Annex A hereto (the “Notice and Questionnaire”) (it being understood and agreed that such form may be modified by the Company in its reasonable discretion to request additional information reasonably necessary to the applicable offering or to omit information not known at the applicable time and no information not so known will be required of any such seller), of the anticipated effective date of any Resale Registration Statement filed pursuant to Section 3 hereof at least 30 days prior to such anticipated effective date. Each Holder, in order to be named in such Resale Registration Statement at the time of its initial effectiveness, will be required to deliver a fully completed and executed Notice and Questionnaire and such other information as the Company may reasonably request in writing, if any, to the Company within 20 days of receipt of notice. From and after the effective date of such Resale Registration Statement, the Company shall use its reasonable best efforts, as promptly as is practicable after the date a fully completed and executed Notice and Questionnaire is delivered, and in any event within 30 days after such date (or five Business Days after the expiration of any Deferral Period in effect when the fully completed and executed Notice and Questionnaire is delivered, if later), (i) if required by applicable law, to file with the SEC a post-effective amendment to such Resale Registration Statement or to prepare and, if permitted or required by applicable law, to file a supplement to the Prospectus or an amendment or supplement to any document incorporated therein by reference or file any other required document so that the Holder delivering such Notice and Questionnaire is named as a selling securityholder in such Resale Registration Statement and any related Prospectus, and so that such Holder is permitted to deliver such Prospectus to purchasers of the Registrable Securities in accordance with applicable law (provided that the Company shall not be required to file more than one supplement or post-effective amendment in any calendar quarter in accordance with this Section 4(p)) and, if the Company shall file a post-effective amendment to such Resale Registration Statement, use its reasonable best efforts to cause such post-effective amendment to be declared effective under the Securities Act as promptly as is practicable; (ii) provide such Holder, upon request, copies of any documents filed pursuant to this Section 4(p); and (iii) notify such Holder as promptly as practicable after the effectiveness under the Securities Act of any post-effective amendment filed pursuant to this Section 4(p); provided that if such Notice and Questionnaire is delivered during a Deferral Period, the Company shall so inform the Holder delivering such Notice and Questionnaire and shall take the actions set forth in clauses (i), (ii) and (iii) above upon expiration of the Deferral Period in accordance with Section 4(q) hereof. Notwithstanding anything contained herein to the contrary, the Company shall be under no obligation to name any Holder that is not a Notice Holder as a selling securityholder in any Registration Statement or Prospectus; provided, however, that any Holder that becomes a Notice Holder pursuant to the provisions of this Section 4(p) (whether or not such Holder was a Notice Holder at the effective date of the applicable Resale Registration Statement) shall be named as a selling securityholder in the such Resale Registration Statement or Prospectus in accordance with the requirements of this Section 4(p).

(q) Upon the occurrence or existence of any pending corporate development, public filings with the SEC or any other material event that, in the reasonable judgment of the Company, makes it appropriate to suspend the availability of the Resale Registration Statement and the Prospectus (including in connection with the filing of a Specified Post-Effective Amendment), the Company shall give notice (without notice of the nature or details of such events) to the

 

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Notice Holders that the availability of the Resale Registration Statement is suspended and, upon receipt of any such notice, each Notice Holder agrees: (i) not to sell any Registrable Securities pursuant to the Resale Registration Statement until such Notice Holder receives copies of the supplemented or amended Prospectus provided for in Section 4(d) hereof, or until it is advised in writing by the Company that the Prospectus may be used, and has received copies of any additional or supplemental filings that are incorporated or deemed incorporated by reference in such Prospectus; and (ii) to hold such notice in confidence. Except in the case of a suspension of the availability of the Resale Registration Statement and the Prospectus solely as the result of the filing of a post-effective amendment or supplement to the Prospectus to add additional selling Holders therein or the filing of a Specified Post-Effective Amendment, the period during which the availability of the Resale Registration Statement and any Prospectus is suspended (the “Deferral Period”) shall not exceed 30 days in any 90-day period or 90 days in any consecutive 12-month period. In the case of a suspension of the availability of the Resale Registration Statement and the Prospectus as a result of the filing of a Specified Post-Effective Amendment, the Deferral Period shall not exceed 20 days or, if the Company receives written comments from the staff of the SEC on such Specified Post-Effective Amendment, 60 days.

(r) Each Holder of Registrable Securities and each Underwriter agrees by acquisition of such Registrable Securities that, upon receipt of any notice from the Company of the happening of any event of the kind described in clause (ii), (iv), (v) or (vi) of Section 4(d) or Section 4(q) hereof, such Holder and such Underwriter will forthwith discontinue disposition of such Registrable Securities covered by a Registration Statement or pursuant to any Prospectus and, in each case, forthwith discontinue dissemination of such Prospectus until such Holder’s or Underwriter’s receipt of the copies of the supplemented or amended Prospectus contemplated by Section 4(d), or until it is advised in writing by the Company that the use of the applicable Prospectus may be resumed, and has received copies of any amendments or supplements thereto and, if so directed by the Company, such Holder or Underwriter, as the case may be, will deliver to the Company all copies, other than permanent file copies, then in such Holder’s or Underwriter’s possession, of the Prospectus covering such Registrable Securities current at the time of the receipt of such notice.

 

5. Registration Expenses

(a) All fees and expenses incident to the performance of or compliance with this Agreement by the Company shall be borne by the Company, whether or not a Resale Registration Statement is filed or becomes effective, including, without limitation, (i) all registration and filing fees, including, without limitation, (A) fees with respect to filings required to be made with FINRA in connection with any underwritten offering and (B) fees and expenses of compliance with state securities or Blue Sky laws as provided in Section 4(g) hereof (including, without limitation, reasonable fees and disbursements of counsel in connection with Blue Sky qualifications of the Registrable Securities and determination of the eligibility of the Registrable Securities for investment under the laws of such jurisdictions as provided in Section 4(g), in the case of Registrable Securities to be sold by a Participating Underwriter), (ii) printing expenses, including, without limitation, expenses of printing Prospectuses if the printing of Prospectuses is requested by the Managing Underwriters, if any, included in any Registration Statement or by any Underwriter during the Effective Period, as the case may be (iii) messenger, telephone and delivery expenses incurred in connection with the performance of their obligations hereunder,

 

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fees and disbursements of counsel for the Company and, only to the extent provided in Section 5(b), the Holders, (iv) fees and disbursements of all independent certified public accountants referred to in Section 4 (including, without limitation, the expenses of any special audit and “comfort” letters required by or incident to such performance), (v) the fees and expenses incurred in connection with the listing of the Securities to be registered on any securities exchange, (vi) Securities Act liability insurance, if the Company desires such insurance, (vii) fees and expenses of all other Persons retained by the Company, (viii) fees and expenses of any “qualified independent underwriter” or other independent appraiser participating in an offering pursuant to Section 3 of Schedule E to the By-laws of FINRA, but only where the need for such a “qualified independent underwriter” arises due to a relationship with the Company, (ix) internal expenses of the Company (including, without limitation, all salaries and expenses of officers and employees of the Company performing legal or accounting duties), (x) the expense of any annual audit, (xi) the fees and expenses of the Trustee and (xii) the expenses relating to printing, word processing and distributing all Registration Statements, Prospectuses, underwriting agreements, securities sales agreements, indentures and any other documents necessary in order to comply with this Agreement.

(b) The Company shall reimburse the Holders for the reasonable fees and disbursements of one Holders’ Counsel. The Company shall reimburse the Holders for fees and expenses (including reasonable fees and expenses of counsel to the Holders) relating to any enforcement of any rights of the Holders under this Agreement.

 

6. Indemnification

(a) Indemnification by the Company. The Company agrees to indemnify and hold harmless each Holder of Registrable Securities and each Underwriter, each Person, if any, who controls each such Holder (within the meaning of Section 15 of the Securities Act or Section 20(a) of the Exchange Act) and the officers, directors and partners of each such Holder, Underwriter and controlling person, to the fullest extent lawful, from and against any and all losses, claims, damages, liabilities, costs (including, without limitation, reasonable costs of preparation and reasonable attorneys’ fees as provided in this Section 6) and expenses (including, without limitation, reasonable costs and expenses incurred in connection with investigating, preparing, pursuing or defending against any of the foregoing) (collectively, “Losses”), as incurred, directly or indirectly caused by, related to, based upon, arising out of or in connection with any untrue or alleged untrue statement of a material fact contained in any Registration Statement, Prospectus or form of prospectus, or in any amendment or supplement thereto, or in any preliminary prospectus, or any omission or alleged omission to state therein a material fact required to be stated therein or necessary to make the statements therein, in light of the circumstances under which they were made, not misleading, except insofar as such Losses are solely based upon information relating to such Holder or Underwriter and furnished in writing to the Company by such Holder or Underwriter or their counsel expressly for use therein. The Company also agrees to indemnify underwriters, selling brokers, dealer managers and similar securities industry professionals participating in the distribution, their officers, directors, agents and employees and each Person who controls such Persons (within the meaning of Section 15 of the Securities Act or Section 20(a) of the Exchange Act) to the same extent as provided above with respect to the indemnification of the Holders or Underwriters.

 

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(b) Indemnification by Holder. In connection with any Registration Statement, Prospectus or form of prospectus, any amendment or supplement thereto, or any preliminary prospectus in which a Holder is participating, such Holder shall furnish to the Company and in writing such information as the Company reasonably request for use in connection with any Registration Statement, Prospectus or form of prospectus, any amendment or supplement thereto, or any preliminary prospectus and shall indemnify and hold harmless the Company, its directors and each Person, if any, who controls the Company (within the meaning of Section 15 of the Securities Act and Section 20(a) of the Exchange Act), and the directors, officers and partners of such controlling persons, to the fullest extent lawful, from and against all Losses arising out of or based upon any untrue or alleged untrue statement of a material fact contained in any Registration Statement, Prospectus or form of prospectus or in any amendment or supplement thereto or in any preliminary prospectus, or any omission or alleged omission to state therein a material fact required to be stated therein or necessary to make the statements therein, in the light of the circumstances under which they were made, not misleading to the extent, but only to the extent, that such Losses are finally judicially determined by a court of competent jurisdiction in a final, unappealable order to have resulted solely from an untrue statement or alleged untrue statement of a material fact or omission or alleged omission of a material fact contained in or omitted from any information so furnished in writing by such Holder to the Company expressly for use therein. Notwithstanding the foregoing, in no event shall the liability of any selling Holder be greater in amount than such Holder’s Maximum Contribution Amount (as defined below).

(c) Conduct of Indemnification Proceedings. If any proceeding shall be brought or asserted against any Person entitled to indemnity hereunder (an “Indemnified Party”), such Indemnified Party shall promptly notify the party or parties from which such indemnity is sought (the “Indemnifying Party” or “Indemnifying Parties,” as applicable) in writing; but the omission to so notify the Indemnifying Party (i) will not relieve such Indemnifying Party from any liability under paragraph (a) or (b) above unless and only to the extent it is materially prejudiced as a result thereof and (ii) will not, in any event, relieve the Indemnifying Party from any obligations to any Indemnified Party other than the indemnification obligation provided in paragraphs (a) and (b) above.

The Indemnifying Party shall have the right, exercisable by giving written notice to an Indemnified Party, within 20 Business Days after receipt of written notice from such Indemnified Party of such proceeding, to assume, at its expense, the defense of any such proceeding; provided, that an Indemnified Party shall have the right to employ separate counsel in any such proceeding and to participate in the defense thereof, but the fees and expenses of such counsel shall be at the expense of such Indemnified Party or parties unless: (1) the Indemnifying Party has agreed to pay such fees and expenses; (2) the Indemnifying Party shall have failed promptly to assume the defense of such proceeding or shall have failed to employ counsel reasonably satisfactory to such Indemnified Party; or (3) the named parties to any such proceeding (including any impleaded parties) include both such Indemnified Party and the Indemnifying Party or any of its affiliates or controlling persons, and such Indemnified Party shall have been advised by counsel that there may be one or more defenses available to such Indemnified Party that are in addition to, or in conflict with, those defenses available to the Indemnifying Party or such affiliate or controlling person (in which case, if such Indemnified Party notifies the Indemnifying Parties in writing that it elects to employ separate counsel at the expense of the Indemnifying

 

15


Parties, the Indemnifying Parties shall not have the right to assume the defense and the reasonable fees and expenses of such counsel shall be at the expense of the Indemnifying Party; it being understood, however, that, the Indemnifying Party shall not, in connection with any one such proceeding or separate but substantially similar or related proceedings in the same jurisdiction, arising out of the same general allegations or circumstances, be liable for the fees and expenses of more than one separate firm of attorneys (together with appropriate local counsel) at any time for such Indemnified Party).

No Indemnifying Party shall be liable for any settlement of any such proceeding effected without its written consent, which shall not be unreasonably withheld, but if settled with its written consent, or if there be a final judgment for the plaintiff in any such proceeding, each Indemnifying Party jointly and severally agrees, subject to the exceptions and limitations set forth above, to indemnify and hold harmless each Indemnified Party from and against any and all Losses by reason of such settlement or judgment. The Indemnifying Party shall not consent to the entry of any judgment or enter into any settlement unless such judgment or settlement (i) includes as an unconditional term thereof the giving by the claimant or plaintiff to each Indemnified Party of a release, in form and substance reasonably satisfactory to the Indemnified Party, from all liability in respect of such proceeding for which such Indemnified Party would be entitled to indemnification hereunder (whether or not any Indemnified Party is a party thereto) and (ii) does not include a statement as to or an admission of fault, culpability or a failure to act by or on behalf of any Indemnified Party.

(d) Contribution. If the indemnification provided for in this Section 6 is unavailable to an Indemnified Party or is insufficient to hold such Indemnified Party harmless for any Losses in respect of which this Section 6 would otherwise apply by its terms (other than by reason of exceptions provided in this Section 6), then each applicable Indemnifying Party, in lieu of indemnifying such Indemnified Party, shall have a joint and several obligation to contribute to the amount paid or payable by such Indemnified Party as a result of such Losses, in such proportion as is appropriate to reflect the relative fault of the Indemnifying Party, on the one hand, and such Indemnified Party, on the other hand, in connection with the actions, statements or omissions that resulted in such Losses as well as any other relevant equitable considerations. The relative fault of such Indemnifying Party, on the one hand, and Indemnified Party, on the other hand, shall be determined by reference to, among other things, whether any untrue or alleged untrue statement of a material fact or omission or alleged omission to state a material fact relates to information supplied by such Indemnifying Party or Indemnified Party, and the parties’ relative intent, knowledge, access to information and opportunity to correct or prevent any such statement or omission. The amount paid or payable by an Indemnified Party as a result of any Losses shall be deemed to include any legal or other fees or expenses incurred by such party in connection with any proceeding, to the extent such party would have been indemnified for such fees or expenses if the indemnification provided for in Section 6(a) or 6(b) hereof was available to such party.

The parties hereto agree that it would not be just and equitable if contribution pursuant to this Section 6(d) were determined by pro rata allocation or by other method of allocation that does not take account of the equitable considerations referred to in the immediately preceding paragraph. Notwithstanding the provisions of this Section 6(d), a selling Holder shall not be required to contribute, in the aggregate, any amount in excess of such Holder’s Maximum

 

16


Contribution Amount. A selling Holder’s “Maximum Contribution Amount” shall equal the excess of (i) the aggregate proceeds received by such Holder pursuant to the sale of such Registrable Securities over (ii) the aggregate amount of damages that such Holder has otherwise been required to pay by reason of such untrue or alleged untrue statement or omission or alleged omission. No person guilty of fraudulent misrepresentation (within the meaning of Section 11(f) of the Securities Act) shall be entitled to contribution from any Person who was not guilty of such fraudulent misrepresentation. The Holders’ obligations to contribute pursuant to this Section 6(d) are several in proportion to the respective principal amount of the Registrable Securities held by each Holder hereunder and not joint.

The indemnity and contribution agreements contained in this Section 6 are in addition to any liability that the Indemnifying Parties may have to the Indemnified Parties.

 

7. Rule 144

The Company covenants that, for so long as any Registrable Securities remain outstanding, it will (a) file the reports required to be filed by it (if so required) under the Securities Act and the Exchange Act in a timely manner and, if at any time the Company is not required to file such reports, it will, upon the written request of any Holder of Registrable Securities, make publicly available other information necessary to permit sales of Registrable Securities pursuant to Rule 144 and (b) take such further action as any Holder may reasonably request in writing, all to the extent required from time to time to enable such Holder to sell Registrable Securities without registration under the Securities Act pursuant to the exemption provided by Rule 144. Upon the request of any Holder, the Company shall deliver to such Holder a written statement as to whether it has complied with such information and requirements.

 

8. Underwritten Registrations of Registrable Securities

If any of the Registrable Securities covered by any Resale Registration Statement are to be sold in an underwritten offering, the investment bank or investment banks and manager or managers that will manage the offering will be selected by the Holders of a majority in aggregate principal amount of such Registrable Securities included in such offering; provided, however, that such investment bank or investment banks and manager or managers must be reasonably acceptable to the Company. For the avoidance of doubt, the Underwriters in any Qualified PO will be selected by the Company in its sole discretion.

No Holder of Registrable Securities may participate in any underwritten registration hereunder unless such Holder (a) agrees to sell such Holder’s Registrable Securities on the basis provided in any underwriting arrangements approved by the Persons entitled hereunder to approve such arrangements and (b) completes and executes all questionnaires, powers of attorney, indemnities, underwriting agreements and other documents required under the terms of such underwriting arrangements.

 

9. Miscellaneous

(a) Remedies. In the event of a breach by the Company of any of its obligations under this Agreement, each Holder, in addition to being entitled to exercise all rights provided herein, in the Indenture or, in the case of the Initial Purchasers, in the Purchase Agreement, or

 

17


granted by law, including recovery of damages, will be entitled to specific performance of its rights under this Agreement. The Company agrees that monetary damages would not be adequate compensation for any loss incurred by reason of a breach by the Company of any of the provisions of this Agreement and hereby further agrees that, in the event of any action for specific performance in respect of such breach, the Company shall waive the defense that a remedy at law would be adequate.

(b) No Inconsistent Agreements. The Company has not entered, as of the date hereof, and the Company shall not enter, after the date of this Agreement, into any agreement with respect to any of its securities that is inconsistent with the rights expressly granted to the Holders in this Agreement or otherwise conflicts with the provisions hereof.

(c) Amendments and Waivers. The provisions of this Agreement may not be amended, modified or supplemented, and waivers or consents to departures from the provisions hereof may not be given, otherwise than with the prior written consent of the Company and the Holders of not less than a majority in aggregate principal amount of the then outstanding Registrable Securities in circumstances that would adversely affect any Holders of Registrable Securities; provided, however, that Section 6 hereof and this Section 9(c) may not be amended, modified or supplemented without the prior written consent of each Holder. Notwithstanding the foregoing, a waiver or consent to depart from the provisions hereof with respect to a matter that relates exclusively to the rights of Holders of Registrable Securities whose securities are being sold pursuant to a Registration Statement and that does not directly or indirectly affect, impair, limit or compromise the rights of other Holders of Registrable Securities may be given by Holders of at least a majority in aggregate principal amount of the Registrable Securities being tendered or being sold by such Holders pursuant to such Registration Statement.

(d) Notices. All notices and other communications provided for or permitted hereunder shall be made in writing by hand delivery, registered first-class mail, next-day air courier or telecopier:

 

  (i) if to a Holder, at the most current address of such Holder, as the case may be, set forth on the records of the registrar of the Notes, with a copy in like manner to the Initial Purchasers as follows:

Citigroup Global Markets Inc.

Credit Suisse Securities (USA) LLC

Global Hunter Securities, LLC/Sea Port Group Securities, LLC

As Representatives of the Initial Purchasers

c/o Citigroup Global Markets Inc.

388 Greenwich Street

New York, New York 10013

Attention: General Counsel

 

18


with copies, which shall not be considered notice, to:

Mayer Brown LLP 700

Louisiana Street, Suite 3400

Houston, Texas 77002

Attention: Kirk Tucker

 

  (ii) if to the Initial Purchasers, at the address specified in Section 9(d)(i);

 

  (iii) if to the Company, as follows:

Energy & Exploration Partners, Inc.

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, Texas 76102

Attention: Legal Department

with a copy to:

Bracewell & Giuliani LLP

711 Louisiana Street, Suite 2300

Houston, Texas 77002

Attention: Charles H. Still, Jr.

All such notices and communications shall be deemed to have been duly given: when delivered by hand, if personally delivered; five Business Days after being deposited in the United States mail, postage prepaid, if mailed; one Business Day after being timely delivered to a next-day air courier guaranteeing overnight delivery; and when receipt is acknowledged by the addressee, if telecopied.

Copies of all such notices, demands or other communications shall be concurrently delivered by the Person giving the same to the Trustee at the address specified in such Indenture.

(e) Successors and Assigns. This Agreement shall inure to the benefit of and be binding upon the successors and assigns of each of the parties hereto, including, without limitation and without the need for an express assignment, subsequent Holders.

(f) Counterparts. This Agreement may be executed in any number of counterparts and by the parties hereto in separate counterparts, each of which when so executed shall be deemed to be an original and all of which taken together shall constitute one and the same agreement.

(g) Headings. The headings in this Agreement are for convenience of reference only and shall not limit or otherwise affect the meaning hereof.

(h) Governing Law. THIS AGREEMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK. EACH OF THE PARTIES HERETO HEREBY IRREVOCABLY SUBMITS TO THE JURISDICTION OF ANY NEW YORK STATE COURT SITTING IN THE BOROUGH OF

 

19


MANHATTAN IN THE CITY OF NEW YORK OR ANY FEDERAL COURT SITTING IN THE BOROUGH OF MANHATTAN IN THE CITY OF NEW YORK IN RESPECT OF ANY SUIT, ACTION OR PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT, AND IRREVOCABLY ACCEPTS FOR ITS AND IN RESPECT OF ITS PROPERTY, GENERALLY AND UNCONDITIONALLY, JURISDICTION OF THE AFORESAID COURTS. EACH OF THE PARTIES HERETO IRREVOCABLY WAIVES, TO THE FULLEST EXTENT IT MAY EFFECTIVELY DO SO UNDER APPLICABLE LAW, TRIAL BY JURY AND ANY OBJECTION THAT IT MAY NOW OR HEREAFTER HAVE TO THE LAYING OF VENUE OF ANY SUCH SUIT, ACTION OR PROCEEDING BROUGHT IN ANY SUCH COURT AND ANY CLAIM THAT ANY SUCH SUIT, ACTION OR PROCEEDING BROUGHT IN ANY SUCH COURT HAS BEEN BROUGHT IN AN INCONVENIENT FORUM. EACH OF THE PARTIES HERETO IRREVOCABLY CONSENTS, TO THE FULLEST EXTENT IT MAY EFFECTIVELY DO SO UNDER APPLICABLE LAW, TO THE SERVICE OF PROCESS OF ANY OF THE AFOREMENTIONED COURTS IN ANY SUCH ACTION OR PROCEEDING BY THE MAILING OF COPIES THEREOF BY REGISTERED OR CERTIFIED MAIL, POSTAGE PREPAID, TO SUCH PARTIES AT THEIR SAID ADDRESS, SUCH SERVICE TO BECOME EFFECTIVE 30 DAYS AFTER SUCH MAILING. NOTHING HEREIN SHALL AFFECT THE RIGHT OF ANY HOLDER TO SERVE PROCESS IN ANY OTHER MANNER PERMITTED BY LAW OR TO COMMENCE LEGAL PROCEEDINGS OR OTHERWISE PROCEED AGAINST THE PARTIES HERETO IN ANY OTHER JURISDICTION.

(i) Severability. If any term, provision, covenant or restriction of this Agreement is held by a court of competent jurisdiction to be invalid, illegal, void or unenforceable, the remainder of the terms, provisions, covenants and restrictions set forth herein shall remain in full force and effect and shall in no way be affected, impaired or invalidated, and the parties hereto shall use their best efforts to find and employ an alternative means to achieve the same or substantially the same result as that contemplated by such term, provision, covenant or restriction. It is hereby stipulated and declared to be the intention of the parties that they would have executed the remaining terms, provisions, covenants and restrictions without including any of such that may be hereafter declared invalid, illegal, void or unenforceable.

(j) Securities Held by the Company or Its Affiliates. Whenever the consent or approval of Holders of a specified percentage of Registrable Securities is required hereunder, Registrable Securities held by the Company or its affiliates (as such term is defined in Rule 405 under the Securities Act) shall not be counted in determining whether such consent or approval was given by the Holders of such required percentage.

(k) Third Party Beneficiaries. Holders and Underwriters are intended third party beneficiaries of this Agreement and this Agreement may be enforced by such Persons.

(l) Entire Agreement. This Agreement, together with the Purchase Agreement and the Indenture, is intended by the parties as a final and exclusive statement of the agreement and understanding of the parties hereto in respect of the subject matter contained herein and therein and any and all prior oral or written agreements, representations, or warranties, contracts, understanding, correspondence, conversations and memoranda between the Initial Purchasers on the one hand and the Company on the other, or between or among any agents, representatives, parents, subsidiaries, affiliates, predecessors in interest or successors in interest with respect to the subject matter hereof and thereof are merged herein and replaced hereby.

 

20


IN WITNESS WHEREOF, the parties have executed this Agreement as of the date first written above.

 

ENERGY & EXPLORATION PARTNERS, INC.
By:  

/s/ B. Hunt Pettit

Name:   B. Hunt Pettit
Title:   President and Chief Executive Officer

Registration Rights Agreement Signature Page


Accepted and Agreed to:
CITIGROUP GLOBAL MARKETS INC.
By:  

/s/ Dylan C. Tormy

  Name: Dylan C. Tormy
  Title: Managing Director
CREDIT SUISSE SECURITIES (USA) LLC
By:  

/s/ Timothy Perry

  Name: Timothy Perry
  Title: Managing Director
GLOBAL HUNTER SECURITIES, LLC
By:  

/s/ Gary E. Meinger

  Name: Gary E. Meinger
  Title: General Counsel
SEA PORT GROUP SECURITIES, LLC
By:  

/s/ Jonathan Silverman

  Name: Jonathan Silverman
  Title: General Counsel

Registration Rights Agreement Signature Page


Annex A

FORM OF SELLING SECURITYHOLDER NOTICE AND QUESTIONNAIRE

The undersigned beneficial holder of 8.0% Convertible Subordinated Notes due 2019 (the “Notes”) of Energy & Exploration Partners, Inc., a Delaware corporation (the “Company”) or common stock of the Company issuable upon conversion of the Notes, understands that the Company has filed or intends to file with the Securities and Exchange Commission a Piggyback Registration Statement on Form S-1 for the registration and resale under the Securities Act or a Resale Registration Statement for the registration and resale under Rule 415 of the Securities Act of, in each case, the Registrable Securities in accordance with the terms of the Registration Rights Agreement, dated July 22, 2014, by and among the Company and the Initial Purchasers named therein (the “Registration Rights Agreement”). A copy of the Registration Rights Agreement is available from the Company upon request at the address set forth below. All capitalized terms not otherwise defined herein shall have the meaning ascribed thereto in the Registration Rights Agreement.

Each beneficial owner of Registrable Securities is entitled to the benefits of the Registration Rights Agreement. In order to sell or otherwise dispose of any Registrable Securities pursuant to a Piggyback Registration Statement or a Resale Registration Statement, a beneficial owner of Registrable Securities generally will be required to be named as a Selling Securityholder in the related prospectus, deliver a prospectus to purchasers of Registrable Securities and be bound by those provisions of the Registration Rights Agreement applicable to such beneficial owner (including certain indemnification provisions as described below).

Any beneficial owner of Registrable Securities wishing to include its Registrable Securities must deliver to the Company a properly completed and signed Notice and Questionnaire. If you do not complete this Notice and Questionnaire and deliver it to the Company within 15 days, in the case of a Piggyback Registration Statement, or within 20 days, in the case of a Resale Registration Statement, of the date of delivery of this Notice and Questionnaire, you will not initially be named as a selling stockholder in the prospectus and therefore will not be permitted to sell any Registrable Securities pursuant to the Registration Statement, except, in the case of a Resale Registration Statement, if the applicable prospectus is updated to so name you as a selling stockholder pursuant to the terms and subject to the conditions of the Registration Rights Agreement. Beneficial owners are encouraged to complete, execute and deliver this Notice and Questionnaire prior to the effectiveness of any Resale Registration Statement so that such beneficial owners may be named as Selling Securityholders in the related prospectus at the time of effectiveness.

Certain legal consequences arise from being named as Selling Securityholders in the applicable Piggyback Registration Statement or Resale Registration Statement and the related prospectus. Accordingly, holders and beneficial owners of Registrable Securities are advised to consult their own securities law counsel regarding the consequences of being named or not being named as a Selling Securityholder in the applicable Piggyback Registration Statement or Resale Registration Statement and the related prospectus.

 

Annex A-1


Please note that, under the terms of the Indenture, you may not effect certain transactions related to the Registrable Securities specified in the Indenture during the Lock-up Period (as defined in the Indenture).

Notice

The undersigned beneficial owner (the “Selling Securityholder”) of Notes and/or Registrable Securities hereby gives notice to the Company of its intention to sell or otherwise dispose of Registrable Securities beneficially owned (or to be owned) by it and listed below in Item 3 pursuant to the applicable Piggyback Registration Statement or Resale Registration Statement. The undersigned, by signing and returning this Notice and Questionnaire, understands that it will be bound by the terms and conditions of this Notice and Questionnaire and the Registration Rights Agreement.

Pursuant to the Registration Rights Agreement, the undersigned has agreed to indemnify and hold harmless the Company and each of its directors, officers and partners and each person, if any, who controls the Company within the meaning of either Section 15 of the Securities Act or Section 20 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), from and against some losses arising in connection with statements concerning the undersigned made in the Registration Statement or the related prospectus in reliance upon the information provided in this Notice and Questionnaire. The Selling Securityholder hereby acknowledges its indemnification obligations under the Registration Rights Agreement.

 

1.    (a)    Full Legal Name of Selling Securityholder:
     

 

   (b)    Full Legal Name of Registered Holder (if not the same as (a) above) through which Notes or Registrable Securities listed in Item 3 below are held:
     

 

   (c)    Full Legal Name of DTC Participant (if applicable and if not the same as (b) above) through which Notes or Registrable Securities listed in Item 3 below are held:
     

 

2.    Address for Notices to Selling Securityholder:
  

 

  

 

   Telephone:                                                                                                                                                                                                             
   Fax:                                                                                                                                                                                                                          

 

Annex A-2


Email address:                                           

Contact person:                                           

 

3. Beneficial Ownership of other Company securities owned by the Selling Securityholder:

Except as set forth below in this Item 4, the undersigned is not the beneficial or registered owner of any securities of the Company other than the Notes or Registrable Securities listed above in Item 3.

 

  (a) Type and amount of other securities beneficially owned by the Selling Securityholder:

 

 

 

 

 

  (b) CUSIP No(s). of such other securities beneficially owned:

 

 

 

 

 

4. Relationship with the Company:

 

  (a) Have you or any of your affiliates, officers, directors or principal equity holders (owners of 5% or more of the equity securities of the Selling Securityholder) held any position or office or have you had any other material relationship with the Company (or its predecessors or affiliates) within the past three years?

¨     Yes

¨     No

 

  (b) If so, please state the nature and duration of your relationship with the Company:

 

 

 

 

 

5. Broker-Dealer Status

Is the Selling Securityholder a broker-dealer registered pursuant to Section 15 of the Exchange Act?

¨     Yes

¨    No

 

Annex A-3


Note that we will be required to identify any registered broker-dealer as an underwriter in the prospectus. If so, please answer the remaining questions in this section.

If the Selling Securityholder is a registered broker-dealer, please indicate whether the Selling Securityholder purchased its Notes or Registrable Securities for investment or acquired them as transaction-based compensation for investment banking or similar services.

¨     purchased the Notes or Registrable Securities for investment

¨     acquired the Notes or Registrable Securities as transaction-based compensation

If the Selling Securityholder is a registered broker-dealer and received its Notes or Registrable Securities other than as transaction-based compensation, the Company is required to identify the Selling Securityholder as an underwriter in the Resale Registration Statement and related prospectus.

 

  (a) Affiliation with Broker-Dealers:

Is the Selling Securityholder an affiliate of a registered broker-dealer? For purposes of this Item 5(b), an “affiliate” of a specified person or entity means a person or entity that directly, or indirectly through one or more intermediaries, controls or is controlled by, or is under common control with, the person or entity specified.

¨     Yes

¨     No

If so, please answer the following three questions in this section.

 

  (i) Please describe the affiliation between the Selling Securityholder and any registered broker-dealers:

 

 

 

 

 

 

 

  (ii) If the Notes or Registrable Securities were purchased by the Selling Securityholder other than in the ordinary course of business, please describe the circumstances:

 

 

 

 

 

   

 

 

 

 

 

Annex A-4


  (iii) If the Selling Securityholder, at the time of its purchase of the Notes or Registrable Securities, has had any agreements or understandings, directly or indirectly, with any person to distribute the Notes or Registrable Securities, please describe such agreements or understandings:

 

 

 

 

 

Note that if the Selling Securityholder is an affiliate of a broker-dealer and did not purchase its notes in the ordinary course of business or at the time of the purchase had any agreements or understandings, directly or indirectly, to distribute the securities, we must identify the Selling Securityholder as an underwriter in the prospectus.

 

6. Nature of Beneficial Holding. The purpose of this question is to identify the ultimate natural person(s) or publicly held entity that exercise(s) sole or shared voting or dispositive power over the Registrable Securities.

 

  (a) Is the Selling Securityholder a natural person?

¨     Yes

¨     No

 

  (b) Is the Selling Securityholder required to file, or is it a wholly owned subsidiary of a company that is required to file, periodic and other reports (for example, Forms 10-K, 10-Q and 8-K) with the Securities and Exchange Commission pursuant to Section 13(a) or 15(d) of the Exchange Act?

¨    Yes

¨     No

 

  (c) Is the Selling Securityholder an investment company, or a subsidiary of an investment company, registered under the Investment Company Act of 1940, as amended?

¨    Yes

¨    No

 

  (d) If a subsidiary, please identify the publicly held parent entity, if any:

 

 

 

Annex A-5


If you answered “No” to questions (a), (b) and (c) above, please identify the controlling person(s) of the Selling Securityholder (the “Controlling Entity”). If the Controlling Entity is not a natural person or a publicly held entity, please identify each controlling person(s) of such Controlling Entity. This process should be repeated until you reach natural persons or a publicly held entity that exercise sole or shared voting or dispositive power over the Registrable Securities:

 

 

 

 

*** PLEASE NOTE THAT THE SECURITIES AND EXCHANGE COMMISSION REQUIRES THAT THESE NATURAL PERSONS BE NAMED IN THE PROSPECTUS.

If you need more space for this response, please attach additional sheets of paper. Please be sure to indicate your name and the number of the item being responded to on each such additional sheet of paper, and to sign each such additional sheet of paper before attaching it to this Notice and Questionnaire. Please note that you may be asked to answer additional questions depending on your responses to the above questions.

 

2. Plan of Distribution:

Except as set forth below, the undersigned (including its donees or pledgees) intends to distribute the Registrable Securities listed above in Item 3 pursuant to the Piggyback Registration Statement or the Resale Registration Statement only as follows (if at all): in the case of a Piggback Registration Statement, such Registrable Securities will be sold through the underwriters named therein in the manner contemplated thereby; and, in the case of a Resale Registration Statement, such Registrable Securities may be sold from time to time directly by the undersigned or alternatively through underwriters, broker-dealers or agents. If the Registrable Securities are sold through underwriters, broker-dealers or agents, the Selling Securityholder will be responsible for underwriting discounts or commissions or agent’s commissions. In the case of a Resale Registration Statement, such Registrable Securities may be sold in one or more transactions at fixed prices, at prevailing market prices at the time of sale, at varying prices determined at the time of sale, or at negotiated prices. Such sales may be effected in transactions (which may involve crosses or block transactions) (i) on any national securities exchange or quotation service on which the Registrable Securities may be listed or quoted at the time of sale, (ii) in the over-the-counter market, (iii) in transactions otherwise than on such exchanges or services or in the over-the-counter market or (iv) through the writing of options. The Selling Securityholder may pledge or grant a security interest in some or all of the Registrable Securities owned by it and, if it defaults in the performance of its secured obligations, the pledgees or secured parties may offer and sell the Registrable Securities from time to time pursuant to the prospectus. The Selling Securityholder also may transfer and donate shares in other circumstances in which case the transferees, donees, pledgees or other successors in interest will be the selling Securityholder for purposes of the prospectus.

 

Annex A-6


State any exceptions here:

Note: In no event may such method(s) of distribution take the form of an underwritten offering of the Registrable Securities without the prior agreement of the Company.

The Company hereby advises each selling securityholder of the publicly available Compliance and Disclosure Interperation promulgated by the SEC regarding short selling:

“An issuer filed a Form S-3 registration statement for a secondary offering of common stock which is not yet effective. One of the selling shareholders wanted to do a short sale of common stock “against the box” and cover the short sale with registered shares after the effective date. The issuer was advised that the short sale could not be made before the registration statement becomes effective, because the shares underlying the short sale are deemed to be sold at the time such sale is made. There would, therefore, be a violation of Section 5 if the shares were effectively sold prior to the effective date.”

By returning this Notice and Questionnaire, the Selling Securityholder will be deemed to be aware of the foregoing interpretation.

 

3. Securities Received From Named Selling Securityholder:

Did the Selling Securityholder receive its Notes or Registrable Securities listed above in Item 3 as a transferee from selling securityholder(s) previously identified in the Resale Registration Statement?

¨     Yes

¨     No

If so, please answer the following two questions in this section:

 

  (i) Did the Selling Securityholder receive such Notes or Registrable Securities listed above in Item 3 from the named selling securityholder(s) prior to the effectiveness of the Resale Registration Statement?

¨     Yes

¨    No

 

  (ii) What is the name(s) of the selling securityholder(s) from whom the Selling Securityholder received the Notes or Registrable Securities listed above in Item 3 and on which date were such securities received?

 

Annex A-7


The undersigned acknowledges that it understands its obligation to comply with the provisions of the Exchange Act and the rules thereunder relating to stock manipulation, particularly Regulation M thereunder (or any successor rules or regulations), in connection with any offering of Registrable Securities pursuant to the Resale Registration Statement. The undersigned agrees that neither it nor any person acting on its behalf will engage in any transaction in violation of such provisions. The Selling Securityholder hereby acknowledges its obligations under the Registration Rights Agreement to indemnify and hold harmless certain persons set forth therein. Pursuant to the Registration Rights Agreement, the Company has agreed under certain circumstances to indemnify the Selling Securityholders against certain liabilities.

In accordance with the undersigned’s obligation under the Registration Rights Agreement to provide such information as may be required by law for inclusion in the Piggyback Registration Statement or the Resale Registration Statement, the undersigned agrees to provide any additional information the Company may reasonably request and to promptly notify the Company of any inaccuracies or changes in the information provided that may occur at any time while the Piggyback Registration Statement or the Resale Registration Statement remains effective. All notices hereunder and pursuant to the Registration Rights Agreement shall be made in writing by hand-delivery, first-class mail, or air courier guaranteeing overnight delivery as follows:

 

To the Company: Energy & Exploration Partners, Inc.
  Two City Place, Suite 1700
  100 Throckmorton
  Attention: Legal Department

In the event any Selling Securityholder transfers all or any portion of the Notes or Registrable Securities listed in Item 3 above after the date on which such information is provided to the Company, the Selling Securityholder will notify the transferee(s) at the time of transfer of its rights and obligations under this Notice and Questionnaire and the Registration Rights Agreement.

By signing this Notice and Questionnaire, the undersigned consents to the disclosure of the information contained herein in its answers to Items 1 through 7 above and the inclusion of such information in the Piggyback Registration Statement or the Resale Registration Statement, the related prospectus and any state securities or Blue Sky applications. The undersigned understands that such information will be relied upon by the Company without independent investigation or inquiry in connection with the preparation or amendment of the Piggyback Registration Statement or the Resale Registration Statement, the related prospectus and any state securities or Blue Sky applications.

 

Annex A-8


Once this Notice and Questionnaire is executed by the Selling Securityholder and received by the Company, the terms of this Notice and Questionnaire and the representations and warranties contained herein shall be binding on, shall inure to the benefit of, and shall be enforceable by the respective successors, heirs, personal representatives and assigns of the Company and the Selling Securityholder with respect to the Notes and/or the Registrable Securities beneficially owned by such Selling Securityholder and listed in Item 3 above. This Notice and Questionnaire shall be governed by, and construed in accordance with, the laws of the State of New York.

IN WITNESS WHEREOF, the undersigned, by authority duly given, has caused this Notice and Questionnaire to be executed and delivered either in person or by its authorized agent.

 

Dated:    

Beneficial Owner:

 

    By:  

 

    Name:  

 

    Title:  

 

PLEASE RETURN THE COMPLETED AND EXECUTED NOTICE AND QUESTIONNAIRE TO:

Energy & Exploration Partners, Inc.

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, Texas 76102

Attention: Legal Department

 

Annex A-9



Exhibit 4.3

SECOND AMENDED AND RESTATED REGISTRATION RIGHTS AGREEMENT

This Second Amended and Restated Registration Rights Agreement (this “Agreement”) is made and entered into as of July 10, 2014 (the “Effective Date”) by and among Energy & Exploration Partners, Inc., a Delaware corporation (the “Company”), and each of the Holders named on Exhibit A hereto. This Agreement amends, restates and replaces in its entirety the Amended and Restated Registration Rights Agreement dated as of April 8, 2013 among the Company and the Holders, as amended by the First Amendment thereto dated as of March 27, 2014 (the “Original Agreement”).

WHEREAS, the Company and the Holders desire to set forth their agreement with respect to certain registration rights and related matters;

NOW, THEREFORE, in consideration of the premises, the mutual covenants contained herein and other valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows:

Section 1. Definitions

Unless otherwise defined herein, as used in this Agreement, the following terms have the following meanings:

Agreement” has the meaning set forth in the preamble.

As-Converted Basis” means, at any time, a basis assuming that all Warrants have been exercised and all shares of Preferred Stock (including shares of Preferred Stock issuable upon exercise of Warrants) have been converted into shares of Common Stock at the exercise and conversion rates then in effect.

Automatic Shelf Registration Statement” means a registration statement filed on Form S-3 (or successor form or other appropriate form under the Securities Act) by a WKSI pursuant to General Instruction I.D. (or other successor or appropriate instruction) of such form.

Business Day” means any day other than a Saturday, Sunday or legal holiday on which banks in New York, New York are authorized or obligated by law to close.

Commission” means the Securities and Exchange Commission.

Common Stock” means shares of common stock of the Company, $0.01 par value per share.

Company” has the meaning set forth in the preamble and includes the Company’s successors by merger, acquisition, reorganization or otherwise.

Convertible Notes” means $375 million principal amount of the Company’s 8.0% Convertible Subordinated Notes due 2019 to be issued on or about July 22, 2014 pursuant to an Indenture to be dated as of July 22, 2014 between the Company and U.S. Bank National Association, as trustee.


Convertible Notes Offering” means the initial offering of the Convertible Notes pursuant to the Purchase Agreement.

Effective Date” has the meaning set forth in the introductory paragraph of this Agreement.

Entity” means any corporation, limited liability company, general partnership, limited partnership, venture, trust, business trust, unincorporated association, estate or other entity.

Exchange Act” means the Securities Exchange Act of 1934, as amended.

Free Writing Prospectus” means a free writing prospectus, as defined in Rule 405 under the Securities Act.

Holder” means any Stockholder, any Warrantholder and any Person to whom rights hereunder are assigned in accordance with Section 9 for so long as any such Person continues to own Registrable Common Stock. Exhibit A hereto sets forth the name and address of each Holder and the number of Shares and Warrants held by each Holder. The Company shall revise Exhibit A from time to time to reflect changes in the information set forth thereon, but the failure of the Company so to revise Exhibit A shall not affect the rights and obligations of the Holders and the Company hereunder.

Initiating Holder(s)” has the meaning set forth in Section 2(a).

Original Agreement” has the meaning set forth in the introductory paragraph of this Agreement.

Permitted Free Writing Prospectus” has the meaning set forth in Section 3.

Person” means any individual or Entity.

Preferred Stock” means the Series A Preferred Stock and the Series B Preferred Stock.

Prospectus” has the meaning set forth in Section 5(a).

Purchase Agreement” means the Purchase Agreement dated July 10, 2014 between the Company and Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC/Seaport Group Securities, LLC, as representatives of the initial purchasers named therein, with respect to the Convertible Notes.

Qualified PO” has the meaning ascribed to such term in the Stockholders Agreement.

Registering Holder” means any Holder of Registrable Common Stock giving the Company a notice pursuant to Section 2 or Section 3 hereof requesting that Registrable Common Stock owned by it be included in a proposed registration.

Registrable Common Stock” means (i) the shares of Common Stock owned by the Holders on the date hereof, (ii) the shares of Common Stock issuable upon the conversion of

 

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shares of Preferred Stock issuable upon the exercise of Warrants owned by the Holders, and (iii) any shares or other securities issued in respect of such shares of Common Stock or issuable upon conversion of such shares of Preferred Stock because of or in connection with any stock dividend, stock distribution, stock split or purchase in any rights offering or in connection with any exchange for or replacement of such shares or any combination of shares, recapitalization, merger or consolidation, or any other equity securities issued pursuant to any other pro rata distribution with respect to such shares of Registrable Common Stock, other than any such shares (a) transferred by a Holder in a transaction in which the Holder’s rights under this Agreement are not assigned pursuant to Section 9 or issuable upon the exercise and/or conversion of any Warrants or shares of Preferred Stock transferred in such a transaction, (b) sold pursuant to an effective registration statement under the Securities Act, or (c) sold in a transaction exempt from the registration and prospectus delivery requirements of the Securities Act (including transactions under Rule 144 or a successor thereto) so that all transfer restrictions and restrictive legends with respect thereto, if any, are removed upon the consummation of such sale. Shares of restricted Common Stock issued to Stockholders under the Company’s 2012 Stock Incentive Plan shall constitute Registrable Common Stock upon the vesting of such restricted Common Stock in accordance with the terms of the awards of such restricted Common Stock and the 2012 Stock Incentive Plan. All references herein to “Holders of Registrable Common Stock,” “ownership of Registrable Common Stock” or “outstanding Registrable Common Stock” or similar references shall be deemed to include Registrable Common Stock that would be outstanding on an As-Converted Basis.

Registration Expenses” means, except for Selling Expenses (as hereinafter defined), all expenses incurred in effecting any registration pursuant to this Agreement, including all registration, qualification and filing fees, listing fees, printing expenses, escrow fees, fees and disbursements of counsel for the Company, blue sky fees and expenses, accountants’ fees and expenses including those related to any special audits incident to or required by any such registration and the reasonable fees and disbursements of one special legal counsel to represent all of the Holders together.

Registration Statement” has the meaning set forth in Section 5(a).

Rule 144” has the meaning set forth in Section 8.

Securities Act” means the Securities Act of 1933, as amended, and the rules and regulations promulgated thereunder.

Selling Expenses” means all underwriting discounts and selling commissions applicable to the securities sold in a transaction or transactions registered on behalf of the Holders.

Series A Preferred Stock” means the Series A Mandatorily Convertible Preferred Stock of the Company.

Series B Preferred Stock” means the Series B Mandatorily Convertible Preferred Stock of the Company.

Shelf Registration Statement” shall mean a registration statement of the Company filed with the Commission on Form S-3 (or any successor form or other appropriate form under the

 

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Securities Act) for an offering to be made on a continuous basis pursuant to Rule 415 under the Securities Act (or any similar rule that may be adopted by the Commission) covering shares of Registrable Common Stock.

Stockholder” means any record holder of shares of Common Stock or Preferred Stock that is a party to this Agreement.

Stockholders Agreement” means the Amended and Restated Stockholders Agreement dated the date hereof among the Company and the Holders, as amended and supplemented from time to time.

Violation” has the meaning set forth in Section 7(a).

Warrantholder” means any record holder of Warrants that is a party to this Agreement.

Warrants” means the warrants to purchase Series A Preferred Stock or Series B Preferred Stock issued pursuant to the Note Purchase Agreement dated as of April 8, 2013 among the Company, as Issuer, Cortland Capital Market Services LLC, as administrative agent for the Holders named therein and the Holders named therein, as amended, supplemented or otherwise modified prior to the date hereof.

WKSI,” or a well-known seasoned issuer, has the meaning set forth in Rule 405 under the Securities Act.

Section 2. Demand Registration Rights

(a) General. If the Company shall receive from any Holder(s) holding at least 20% of the then outstanding shares of Registrable Common Stock, at any time after 180 days after the date of the completion of an Qualified PO, a written request that the Company file a registration statement with respect to any of such Holder’s shares of Registrable Common Stock (the sender(s) of such request or any similar request pursuant to this Agreement shall be known as the “Initiating Holder(s)”), then the Company shall, within ten (10) days of the receipt thereof, give written notice of such request to all Holders, and subject to the limitations of this Section 2, use its reasonable best efforts to effect, as soon as reasonably practicable (and in any event within sixty (60) days after the date such request is given by the Initiating Holders), the registration under the Securities Act of the offer and sale of all shares of Registrable Common Stock that the Holders request to be registered. Notwithstanding anything to the contrary in this Agreement, the Initiating Holders may request that the Company register the sale of such Registrable Common Stock on an appropriate form, including a Shelf Registration Statement (so long as the Company is eligible to use Form S-3) and, if the Company is a WKSI, an Automatic Shelf Registration Statement. The Company shall not be obligated to take any action to effect any such registration:

(i) after it has effected five such registrations pursuant to this Section 2, and such registrations have been declared or ordered effective;

(ii) within six months after a registration pursuant to this Section 2 that has been declared or ordered effective;

 

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(iii) during the period starting with the date 60 days prior to its good faith estimate of the date of filing of, and ending on a date 180 days after the effective date of, a Company-initiated registration pursuant to which Holders would have piggyback registration rights pursuant to Section 3 hereof, provided that the Company is actively employing in good faith all reasonable efforts to cause such registration statement to become effective;

(iv) where the anticipated aggregate offering price of all securities included in such offering is less than (A) $10,000,000, in the event such registration is effected through the filing of a Registration Statement on Form S-1 (or any successor form under the Securities Act), or (B) $5,000,000, in the event such registration is effected through the filing of a Registration Statement on Form S-3 (or any successor or other form under the Securities Act other than Form S-1); or

(v) if the Company shall furnish to such Holders a certificate signed by the President of the Company stating that in the good faith judgment of the board of directors of the Company it would be seriously detrimental to the Company and its equity holders for such registration statement to be filed at the time filing would be required and it is therefore essential to defer the filing of such registration statement, the Company shall have the right to defer such filing for a period of not more than 120 days after receipt of the request of the Initiating Holder(s), provided that the Company shall not defer its obligation in this manner more than once in any twelve month period.

(b) Underwriting. In the event that the Initiating Holders elect to conduct an underwritten offering of Registrable Common Stock pursuant to a registration statement filed pursuant to paragraph (a) of this Section 2, the Company (together with all Holders proposing to distribute their securities through such underwriting) shall enter into an underwriting agreement in customary form with the underwriter or underwriters selected for such underwriting by the Company and reasonably acceptable to the Registering Holders holding a majority of the shares of Registrable Common Stock requested to be included in such registration and underwriting. Notwithstanding any other provision of this Section 2, if the underwriter advises the Registering Holders in writing that marketing factors require a limitation of the number of shares to be underwritten, the number of shares of Registrable Common Stock that may be included in the registration and underwriting shall be allocated among all Registering Holders in proportion, as nearly as practicable, to the respective amounts of Registrable Common Stock requested by such Registering Holders to be included in such registration and underwriting.

If any Holder of Registrable Common Stock disapproves of the terms of the underwriting, such Person may elect to withdraw therefrom by written notice to the Company, the managing underwriter and the Initiating Holder(s). If by the withdrawal of such Registrable Common Stock a greater number of shares of Registrable Common Stock held by other Holders may be included in such registration (up to the maximum of any limitation imposed by the underwriters), then the Company shall offer to all Holders who have included Registrable Common Stock in the registration the right to include additional Registrable Common Stock in the same proportion used in determining the shares that may be included pursuant to the first paragraph of this Section 2(b). If the underwriter has not limited the number of shares of Registrable Common Stock to be underwritten, the Company may include securities for its own account if the underwriter so agrees and if the number of shares of Registrable Common Stock which would otherwise have been included in such registration and underwriting will not thereby be limited.

 

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Section 3. Piggyback Registrations

(a) General. If, at any time or from time to time after the date of the completion of an Qualified PO, the Company shall determine to register the offer and sale of any of its securities for its own account or the account of a stockholder or stockholders exercising their respective demand registration rights (other than a registration pursuant to Section 2 or a registration effected solely to implement an employee benefit plan or a transaction to which Rule 145 of the Securities Act is applicable) in connection with an underwritten offering of its securities for cash on a form which would permit the registration of Registrable Common Stock, the Company will:

 

  (i) promptly (and in any event no later than twenty (20) days prior to the filing of any Registration Statement in connection with such offering) give to each Holder written notice thereof; and

(ii) include in such registration and in the underwriting involved therein, all the Registrable Common Stock specified in a written request or requests, made within ten days after giving of such written notice by the Company, by any Holders (except that (A) if the underwriter determines that marketing factors require a shorter time period and the Company so informs each Holder in the applicable written notice, such written request or requests must be made within five days and (B) in the case of an “overnight” offering or a “bought deal,” such written request or requests must be made within one Business Day), except as set forth in Section 3(b); provided, however, that the Company may withdraw any registration statement described in this Section 3 at any time before it becomes effective, or postpone or terminate the offering of securities under such registration statement, without obligation or liability to any Holder.

(b) Underwriting. The right of any Holder to registration pursuant to this Section 3 shall be conditioned upon such Holder’s participation in the underwriting and the inclusion of such Holder’s Registrable Common Stock in the underwriting to the extent provided herein. All Holders proposing to distribute their Registrable Common Stock through such underwriting shall (together with the Company) enter into an underwriting agreement in customary form with the underwriter or underwriters selected for such underwriting by the Company. Notwithstanding any other provision of this Section 3, in connection with a registration under Section 3(a), if the underwriter determines that marketing factors require a limitation of the number of shares to be underwritten, the Company shall so advise all Registering Holders whose securities would otherwise be registered and underwritten pursuant hereto, and the number of shares of Registrable Common Stock that may be included in the registration and underwriting shall be allocated among all Registering Holders in proportion, as nearly as practicable, to the respective amounts of Registrable Common Stock requested by such Registering Holders to be included in such registration and underwriting, or, if so determined by the underwriter, all Registrable Common Stock shall be excluded from such registration and underwriting; provided, however, that in no event shall the amount of securities of the Registering Holders included in the offering be reduced unless the amount of securities of all other selling equity holders included in the offering are proportionately reduced.

 

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If any Holder disapproves of the terms of any such underwriting, the Holder may elect to withdraw therefrom by written notice to the Company and the underwriter. If, in connection with a registration under Section 3(a), by the withdrawal of such Registrable Common Stock a greater number of shares of Registrable Common Stock held by other Holders may be included in such registration (up to the maximum of any limitation imposed by the underwriters), then the Company shall offer to all Holders who have included Registrable Common Stock in the registration the right to include additional shares of Registrable Common Stock in the same proportion used in determining the shares that may be included pursuant to the first paragraph of this Section 3(b).

Section 4. Selection of Counsel; Registration Expenses

(a) The Holders of a majority of the shares of Registrable Common Stock included in any registration pursuant to Section 2 or 3 hereof shall have the right to designate legal counsel to represent all of the Holders in connection therewith.

(b) All Registration Expenses incurred in connection with any registration, filing, qualification or compliance pursuant to Section 2 or 3 shall be borne by the Company. All Selling Expenses relating to the sale of securities registered by the Holders shall be borne by the holders of such securities pro rata on the basis of the number of shares so sold.

Section 5. Further Obligations

(a) In connection with any registration of the offer and sale of shares of Registrable Common Stock under the Securities Act pursuant to this Agreement, the Company will consult with the Registering Holders concerning the form of underwriting agreement (and shall provide to each Registering Holder the form of underwriting agreement prior to the Company’s execution thereof) in the case of an underwritten offering and shall provide to each Registering Holder and its representatives such other documents (including correspondence with the Commission with respect to the registration statement and the related securities offering) as such Registering Holder shall reasonably request in connection with its participation in such registration. The Company will furnish to each Registering Holder as far in advance as reasonably practicable before filing a Registration Statement or any supplement or amendment thereto or any prospectus forming a part of such Registration Statement (including any preliminary prospectus and any amendments or supplements thereto, the “Prospectus”), upon request, copies of reasonably complete drafts of all such documents proposed to be filed (including exhibits and each document incorporated by reference therein to the extent then required by the rules and regulations of the Commission), and provide each such Registering Holder the opportunity to object to any information pertaining to such Registering Holder and its plan of distribution that is contained therein and make the corrections reasonably requested by such Registering Holder with respect to such information prior to filing such document. In the event that the Company prepares and files with the Commission a registration statement on any appropriate form under the Securities Act (a “Registration Statement”) providing for the sale of Registrable Common Stock held by any Registering Holder pursuant to its obligations under this Agreement, the Company will:

(i) prepare and file with the Commission such Registration Statement with

 

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respect to such Registrable Common Stock, which Registration Statement shall comply as to form in all material respects with the requirements of the applicable form and include all financial statements required by the Commission to be filed therewith, and use its reasonable best efforts to cause such Registration Statement to become effective and keep such Registration Statement effective until the Registering Holders have completed the distribution described in such Registration Statement or until all shares of Registrable Common Stock covered by such Registration Statement have ceased to be Registrable Common Stock;

(ii) prepare and file with the Commission such amendments and post-effective amendments to the Registration Statement as may be necessary to keep such Registration Statement effective; cause the related Prospectus to be supplemented by any required Prospectus supplement, and as so supplemented to be filed pursuant to Rule 424 under the Securities Act; and comply with the provisions of the Securities Act with respect to the disposition of all securities covered by such Registration Statement during the applicable period in accordance with the intended methods of disposition by the participating Holder or Holders thereof set forth in such Registration Statement or supplement to such Prospectus;

(iii) promptly notify the Registering Holders and the managing underwriters, if any, (A) when a Prospectus or any Prospectus supplement or post-effective amendment has been filed, and, with respect to a Registration Statement or any post-effective amendment, when the same has become effective, (B) of any request by the Commission or any state securities commission for amendments or supplements to a Registration Statement or related Prospectus or for additional information, (C) of the issuance by the Commission or any state securities commission of any stop order suspending the effectiveness of a Registration Statement or the initiation of any proceedings for that purpose, (D) of the receipt by the Company of any notification with respect to the suspension of the qualification of any of the Registrable Common Stock for sale in any jurisdiction or the initiation or threatening of any proceeding for such purpose, and (E) of the existence of any fact which results in a Registration Statement, a Prospectus or any document incorporated therein by reference containing an untrue statement of a material fact or omitting to state a material fact required to be stated therein or necessary to make the statements therein not misleading;

(iv) use reasonable best efforts to promptly obtain the withdrawal of any order suspending the effectiveness of a Registration Statement;

(v) if requested by the managing underwriters or a Registering Holder, promptly incorporate in a Prospectus supplement or post-effective amendment such information as the managing underwriters or the Registering Holders holding a majority of the Registrable Common Stock being sold by Registering Holders agree should be included therein relating to the sale of such Registrable Common Stock, including without limitation information with respect to the amount of Registrable Common Stock being sold to such underwriters, the purchase price being paid therefor by such underwriters and with respect to any other terms of the underwritten (or best efforts underwritten) offering of the Registrable Common Stock to be sold in such offering; and make all required filings of such Prospectus supplement or post-effective amendment as soon as notified of the matters to be incorporated in such Prospectus supplement or post-effective amendment;

 

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(vi) furnish to such Registering Holder and each managing underwriter at least one signed copy of the Registration Statement and any post-effective amendment thereto, including financial statements and schedules, all documents incorporated therein by reference and all exhibits (including those incorporated by reference) (provided, however, that any such document made available by the Company through EDGAR shall be deemed so furnished);

(vii) deliver to such Registering Holders and the underwriters, if any, as many copies of the Prospectus (including each preliminary prospectus) and any amendment or supplement thereto and any Permitted Free Writing Prospectus as such persons or entities may reasonably request;

(viii) prior to any public offering of Registrable Common Stock, register or qualify or cooperate with the Registering Holders, the underwriters, if any, and their respective counsel in connection with the registration or qualification of such Registrable Common Stock for offer and sale under the securities or blue sky laws of such jurisdictions within the United States as any Registering Holder or underwriter reasonably requests in writing and do any and all other acts or things necessary or advisable to enable the disposition in such jurisdictions of the Registrable Common Stock covered by the applicable Registration Statement; provided, however, that the Company will not be required to qualify generally to do business in any jurisdiction where it is not then so required to be qualified or to take any action which would subject it to general service of process or taxation in any such jurisdiction where it is not then so subject;

(ix) cooperate with the Registering Holders and the managing underwriters, if any, to facilitate the timely preparation and delivery of certificates representing Registrable Common Stock to be sold pursuant to such Registration Statement and not bearing any restrictive legends, and enable such Registrable Common Stock to be in such denominations and registered in such names as the managing underwriters may request at least one Business Day prior to any sale of Registrable Common Stock to the underwriters;

(x) if any fact described in subparagraph (iii)(E) above exists, promptly prepare and file with the Commission a supplement or post-effective amendment to the applicable Registration Statement or the related Prospectus or any document incorporated therein by reference or file any other required document so that the Registration Statement and the Prospectus, as thereafter delivered to the purchasers of the Registrable Common Stock being sold thereunder, will not contain an untrue statement of a material fact or omit to state any material fact required to be stated therein or necessary to make the statements therein not misleading;

(xi) cause all Registrable Common Stock covered by the Registration Statement to be listed on each securities exchange or automated quotation system on which similar securities issued by the Company are then listed;

(xii) provide a transfer agent and registrar and a CUSIP number for all Registrable Common Stock included in such Registration Statement, not later than the effective date of the applicable Registration Statement;

(xiii) enter into such agreements (including an underwriting agreement in form

 

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reasonably satisfactory to the Company) and take all such other reasonable actions in connection therewith in order to expedite or facilitate the disposition of such Registrable Common Stock, including customary participation of management;

(xiv) in the case of an underwritten offering, use its commercially reasonable efforts to furnish or cause to be furnished to the Registering Holders and the underwriters a signed counterpart, addressed to the Registering Holders and the underwriters, of: (i) an opinion of counsel for the Company, dated the date of each closing under the underwriting agreement, reasonably satisfactory to the underwriters; (ii) a “comfort” letter, dated the date of the underwriting agreement and the date of each closing under the underwriting agreement, signed by the independent registered public accounting firm that has certified the Company’s financial statements included in such Registration Statement, covering substantially the same matters with respect to such Registration Statement (and the Prospectus included therein) and with respect to events subsequent to the date of such financial statements, as are customarily covered in accountants’ letters delivered to underwriters in underwritten public offerings of securities, and such other financial matters as the underwriters may reasonably request and customarily obtained by underwriters in underwritten offerings, provided that, to be an addressee of the comfort letter, the Registering Holders may be required to confirm that they are in the category of persons to whom a comfort letter may be delivered in accordance with applicable accounting literature; and (iii) a “comfort” letter, dated the date of the underwriting agreement and the date of each closing under the underwriting agreement, signed by the independent petroleum engineering firm that has evaluated the Company’s oil and gas reserves included in such Registration Statement, covering substantially the same matters with respect to such Registration Statement (and the Prospectus included therein) and with respect to events subsequent to the date of its evaluation of such oil and gas reserves, as are customarily covered in engineers’ letters delivered to underwriters in underwritten public offerings of securities, and such other related matters as the underwriters may reasonably request and customarily obtained by underwriters in underwritten offerings; and

(xv) make available for inspection by a representative of the Registering Holders whose Registrable Common Stock is being sold pursuant to such Registration Statement, any underwriter participating in any disposition pursuant to a Registration Statement, and any attorney or accountant retained by such Registering Holders or underwriter, all financial and other records and any pertinent corporate documents and properties of the Company reasonably requested by such representative, underwriter, attorney or accountant in connection with such Registration Statement; provided, however, that any records, information or documents that are reasonably determined by the Company to be, and are designated by the Company in writing as, confidential shall be kept confidential by such persons or entities unless disclosure of such records, information or documents is required by court or administrative order.

(b) Notwithstanding anything to the contrary in this Agreement, to the extent the Company is a WKSI, at the time any Registrable Common Stock is registered pursuant to Section 2 hereof, and the Initiating Holders so request, the Company shall file an Automatic Shelf Registration Statement which covers those shares of Registrable Common Stock which are requested to be registered within five Business Days after receipt of such request. If the Company does not pay the filing fee covering the shares of Registrable Common Stock at the

 

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time the Automatic Shelf Registration Statement is filed, the Company agrees to pay such fee at such time or times as the shares of Registrable Common Stock are to be sold. If the Automatic Shelf Registration Statement has been outstanding for at least three years, at the end of the third year the Company shall file a new Automatic Shelf Registration Statement covering the shares of Registrable Common Stock. If at any time when the Company is required to re-evaluate its WKSI status the Company determines that it is not a WKSI, the Company shall use its reasonable best efforts to file a new Shelf Registration Statement on Form S-3 (or amend the Automatic Shelf Registration Statement to a form that the Company is eligible to use) and keep such registration statement effective during the period during which such registration statement is required to be kept effective.

(c) Each Holder agrees that, upon receipt of any notice from the Company of the happening of an event of the kind described in Section 5(a)(iii)(B) through Section 5(a)(iii)(E), such Holder will immediately discontinue disposition of shares of Registrable Common Stock pursuant to the applicable Shelf Registration Statement until such stop order is vacated or such Holder receives a copy of the supplemented or amended Prospectus. If so directed by the Company, each Holder will deliver to the Company (at the reasonable expense of the Company) all copies in its possession, other than permanent file copies then in such Holder’s possession, of the Prospectus covering such shares of Registrable Common Stock at the time of receipt of such notice.

Each Holder represents that it has not prepared or had prepared on its behalf or used or referred to, and agrees that it will not prepare or have prepared on its behalf or use or refer to, any Free Writing Prospectus, and has not distributed and will not distribute any written materials in connection with the offer or sale of the Registrable Common Stock, in each case without the prior express written consent of the Company and, in connection with any underwritten offering, the underwriters. Any such Free Writing Prospectus consented to by, or any Free Writing Prospectus prepared by or on behalf of or otherwise used or referred to by, the Company or the underwriters, as the case may be, is referred to herein as a “Permitted Free Writing Prospectus.” The Company represents and agrees that it has treated and will treat, as the case may be, each Permitted Free Writing Prospectus as an Issuer Free Writing Prospectus (as defined in Rule 433 of the Securities Act), including in respect of timely filing with the Commission, legending and record keeping.

Section 6. Further Information Furnished by Holders

It shall be a condition precedent to the obligations of the Company to take any action pursuant to Sections 2 through 5 that the Holders shall furnish to the Company such information regarding themselves, the Registrable Common Stock held by them, and the intended method of disposition of such securities as shall be reasonably required to effect the registration of the offer and sale of their Registrable Common Stock.

 

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Section 7. Indemnification

In the event any shares of Registrable Common Stock are included in a registration statement under Section 2 or 3:

(a) The Company will indemnify and hold harmless each Holder, each of the officers, directors, managers, shareholders, members, partners, employees and agents of each Holder and each Person, if any, who controls such Holder within the meaning of the Securities Act or Exchange Act, against any losses, claims, damages or liabilities (joint or several) to which they may become subject under the Securities Act, the Exchange Act or other federal or state law, insofar as such losses, claims, damages, or liabilities (or actions in respect thereof) arise out of or are based upon any of the following statements, omissions or violations (collectively a “Violation”): any untrue statement or alleged untrue statement of a material fact contained in such registration statement, including any preliminary prospectus or final prospectus contained therein or any amendments or supplements thereto, or in any Permitted Free Writing Prospectus; the omission or alleged omission to state therein a material fact required to be stated therein, or necessary to make the statements therein not misleading; or any violation or alleged violation by the Company or any officer, director, employee, advisor or affiliate thereof of the Securities Act, the Exchange Act, any state securities law or any rule or regulation promulgated under the Securities Act, the Exchange Act or any state securities law, and the Company will reimburse each such Holder, officer, director, manager, shareholder, member, partner, employee, agent or controlling Person for any legal or other expenses reasonably incurred by them in connection with investigating or defending any such loss, claim, damage, liability, or action; provided, however, that the indemnity agreement contained in this Section 7(a) shall not apply to amounts paid in settlement of any such loss, claim, damage, liability, or action if such settlement is effected without the consent of the Company (which consent shall not be unreasonably withheld, conditioned, delayed or denied), nor shall the Company be liable in any such case for any such loss, claim, damage, liability, or action to the extent that it arises out of or is based upon a Violation which occurs in reliance upon and in conformity with written information furnished expressly for use in connection with such registration by any such Holder.

(b) To the extent permitted by law, each Holder will, if shares of Registrable Common Stock held by such Person are included in the securities as to which such registration, qualification or compliance is being effected, indemnify and hold harmless the Company, each of its directors and officers, each Person, if any, who controls the Company within the meaning of the Securities Act and any other Holder selling securities in such registration statement and each of its officers, directors, managers, shareholders, members, partners, employees and agents or any Person who controls such Holder, against any losses, claims, damages, or liabilities (joint or several) to which the Company or any such other Holder, officer, director, manager, shareholder, member, partner, employee, agent or controlling Person may became subject under the Securities Act, the Exchange Act or other federal or state law, insofar as such losses, claims, damages or liabilities (or actions in respect thereto) arise out of or are based upon any Violation, in each case to the extent (and only to the extent) that such Violation occurs in reliance upon and in conformity with written information furnished by such Holder expressly for use in connection with such registration, and each such Holder will reimburse any legal or other expenses reasonably incurred by the Company or any such underwriter, other Holder, officer, director, manager, shareholder, member, partner, employee, agent or controlling Person in connection with investigating or defending any such loss, claim, damage, liability, or action; provided, however, that the indemnity agreement contained in this Section 7(b) shall not apply to amounts paid in settlement of any such loss, claim, damage, liability or action if such settlement is effected without the consent of such Holder (which consent shall not be unreasonably withheld, conditioned, delayed or denied); and provided, that in no event shall any indemnity under this Section 7(b) exceed the net proceeds from the offering received by such Holder.

 

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(c) Promptly after receipt by an indemnified party under this Section 7 of notice of the commencement of any action (including any governmental action), such indemnified party will, if a claim in respect thereof is to be made against any indemnifying party under this Section 7, notify the indemnifying party in writing of the commencement thereof, and the indemnifying party shall have the right to participate in, and, to the extent the indemnifying party so desires, jointly with any other indemnifying party similarly noticed, to assume the defense thereof with counsel mutually satisfactory to the parties; provided, however, that an indemnified party shall have the right to retain its own counsel, with the fees and expenses to be paid by the indemnifying party, if the indemnifying party has failed to assume the defense or employ counsel reasonably satisfactory to the indemnified party or if the indemnified party shall have been advised by counsel that representation of such indemnified party by the counsel retained by the indemnifying party would be inappropriate due to actual or potential differing interests between such indemnified party and any other party represented by such counsel in such proceeding. The failure of any indemnified party to notify an indemnifying party within a reasonable time of the commencement of any such action shall relieve such indemnifying party of liability to the indemnified party under this Section 7 only to the extent that such failure to give notice shall materially prejudice the indemnifying party in the defense of any such claim or any such litigation, but the omission so to notify the indemnifying party will not relieve it of any liability that it may have to any indemnified party otherwise than under this Section 7.

(d) If the indemnification provided for in this Section 7 is held by a court of competent jurisdiction to be unavailable to an indemnified party with respect to any losses, claims, damages or liabilities referred to herein, the indemnifying party, in lieu of indemnifying such indemnified party thereunder, shall to the extent permitted by applicable law contribute to the amount paid or payable by such indemnified party as a result of such loss, claim, damage or liability in such proportion as is appropriate to reflect the relative fault of the indemnifying party on the one hand and of the indemnified party on the other in connection with the Violation(s) that resulted in such loss, claim, damage or liability, as well as any other relevant equitable considerations. The relative fault of the indemnifying party on the one hand and the indemnified party on the other shall be determined by reference to, among other things, whether the untrue or alleged untrue statement of a material fact or the omission or alleged omission to state a material fact has been made by, or relates to, information supplied by such party, and the parties’ relative intent, knowledge, access to information and opportunity to correct or prevent such statement or omission. The parties hereto agree that it would not be just and equitable if contributions pursuant to this paragraph were to be determined by pro rata allocation or by any other method of allocation that does not take account of the equitable considerations referred to herein. The amount paid by an indemnified party as a result of the losses, claims, damages or liabilities referred to in the first sentence of this paragraph shall be deemed to include any legal and other expenses reasonably incurred by such indemnified party in connection with investigating or defending any loss, claim, damage or liability that is the subject of this paragraph. No person guilty of fraudulent misrepresentation (within the meaning of Section 11(f) of the Securities Act) shall be entitled to contribution from any Person who is not guilty of fraudulent misrepresentation; and in no event shall any contribution by a Holder exceed the net proceeds from the offering received by such Holder.

 

-13-


(e) The obligations of the Company and the Holders under this Section 7 shall survive completion of any offering of Registrable Common Stock pursuant to a registration statement, the expiration of any rights hereunder and the termination of this Agreement.

Section 8. Rule 144 Reporting

With a view to making available to the Holders the benefits of Rule 144 promulgated under the Securities Act (“Rule 144”) and any other rule or regulation of the Commission that may at any time permit a Holder to sell securities of the Company to the public without registration, the Company agrees, after the date of an Qualified PO, to:

(a) make and keep public information available (as those terms are understood and defined in Rule 144) at all times;

(b) file with the Commission in a timely manner all reports and other documents required of the Company under the Exchange Act; and

(c) furnish to any Holder, forthwith upon request, (i) a written statement by the Company that it has complied with the reporting requirements of Rule 144, the Securities Act and the Exchange Act (at any time after it has become subject to such reporting requirements), (ii) a copy of the most recent annual or quarterly report of the Company and such other reports and documents so filed by the Company (provided, however, that any such report or document described in this subsection (ii) made available by the Company through EDGAR shall be deemed so furnished), and (iii) such other information as may be reasonably requested in availing any Holder of any rule or regulation of the Commission which permits the selling of any such securities without registration or pursuant to such form.

Section 9. Assignment of Rights

For so long as this Agreement is in effect, the rights to cause the Company to register Registrable Common Stock pursuant to Section 2 or 3 may only be assigned to (i) a person referred to in clauses (a) - (e) of clause (2) of the definition of Permitted Transfer in the Stockholders Agreement or (ii) any other assignee that will hold 5% or more of the issued and outstanding shares of Common Stock on an As-Converted Basis following such assignment, without the prior consent of the Company. Subject to the foregoing, any assignment pursuant to this Section 9 shall be conditioned upon written notice to the Company identifying the name and address of the assignee and any other material information as to the identity of such assignee as may be reasonably requested and to compliance with the Stockholders Agreement to the extent applicable. Notwithstanding anything to the contrary contained in this Section 9 but subject to the terms of the Stockholders Agreement and the Warrants, any Holder may elect to transfer all or a portion of its shares of Registrable Common Stock, Warrants or shares of Preferred Stock to any third party (to the extent such transfer is otherwise permissible) without assigning its rights hereunder with respect thereto; provided, that in any such event all rights under this Agreement with respect to such shares of Registrable Common Stock and the shares of Registrable Common Stock issuable upon the exercise and/or conversion of such Warrants or shares of Preferred Stock so transferred shall cease and terminate.

 

-14-


Section 10. Amendment of Registration Rights

Any provision of this Agreement may be amended and the observance thereof may be waived (either generally or in a particular instance and either retroactively or prospectively) only with the written consent of the Company and the Holders of 75% of the then outstanding Registrable Common Stock. Any amendment or waiver effected in accordance with this Section 10 shall be binding upon each Holder and the Company; provided, however, that no such amendment that materially and adversely affects the rights of any Holder shall be binding on such Holder without such Holder’s written consent. Notwithstanding the foregoing, the Company may, without the consent of any Holder, amend this Agreement solely for the purpose of adding as a Holder party to this Agreement, and granting to such person the registration rights provided hereunder, any person who acquires shares of capital stock of the Company or securities exercisable or exchangeable for or convertible into shares of capital stock of the Company prior to the consummation of an Qualified PO.

Section 11. Expiration, Termination and Delay of Registration

(a) A Holder’s registration rights hereunder shall expire at such time as all shares of Registrable Common Stock held by such Holder cease to be Registrable Common Stock.

(b) The Company shall have no further obligations pursuant to this Agreement at such time as no shares of Registrable Common Stock are outstanding after their original issuance; provided, that the Company’s obligations under Sections 4, 7 and 14 (and any related definitions) shall remain in full force and effect following such time.

(c) No Holder shall have any right to obtain or seek an injunction restraining or otherwise delaying any such registration as the result of any controversy that might arise with respect to the interpretation or implementation of this Agreement.

Section 12. Limitations on Subsequent Registration Rights

From and after the date hereof, the Company may, without the prior written consent of the Holders, enter into any agreement with any holder or prospective holder of any securities of the Company which provides such holder or prospective holder of securities of the Company comparable, but not materially more favorable, registration rights to those granted to the Holders hereby. Notwithstanding the foregoing, the Company may, without the consent of any Holder, enter into a registration rights agreement with the initial purchasers of the Convertible Notes in the Convertible Notes Offering providing for registration rights with respect to the shares of Common Stock issuable upon conversion of the Convertible Notes consistent with the terms described in the Offering Memorandum for the Convertible Notes Offering dated July 10, 2014.

Section 13. “Market Stand-off” Agreement

Each Holder hereby agrees that it will not, to the extent requested by the Company and any underwriter of securities of the Company, sell or otherwise transfer or dispose of any Registrable Common Stock, except securities included in such registration, during a period, not to exceed 180 days, following the date of the final prospectus for a firm commitment underwritten offering of Common Stock by the Company, and it will enter into agreements with the managing underwriters, if any, in connection with any such sale to give effect to the foregoing; provided, however, that all other Persons with registration rights (whether or not

 

-15-


pursuant to this Agreement) and all executive officers and directors of the Company enter into similar agreements. In order to enforce the foregoing covenant, the Company may impose stop-transfer instructions with respect to the Registrable Common Stock of each Holder (and the shares or securities of every other Person subject to the foregoing restriction) until the end of such period.

Section 14. Miscellaneous

(a) Notices. All notices and other communications provided for or permitted hereunder shall be in writing and shall be deemed to have been duly given and received when delivered by overnight courier or hand delivery, when sent by telecopy, or five days after mailing if sent by registered or certified mail (return receipt requested) postage prepaid, to the Parties at the following addresses (or at such other address for any Party as shall be specified by like notices, provided that notices of a change of address shall be effective only upon receipt thereof).

If to the Company, at:

Energy & Exploration Partners, Inc.

Attn: General Counsel

Two City Place, Suite 1700

100 Throckmorton

Fort Worth, Texas 76102

If to any Holder of Registrable Common Stock, to such Person’s address as set forth on the records of the Company.

(b) Counterparts. This Agreement may be executed in any number of counterparts, each of which shall be deemed an original, but all of which together shall constitute one and the same instrument.

(c) Headings. The section and paragraph headings contained in this Agreement are for reference purposes only and shall not affect in any way the meaning or interpretation of this Agreement.

(d) Governing Law. THIS AGREEMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF DELAWARE, EXCLUDING ANY CONFLICT-OF-LAWS RULE OR PRINCIPLE THAT MIGHT REFER THE GOVERNANCE OR THE CONSTRUCTION OF THIS AGREEMENT TO THE LAW OF ANOTHER JURISDICTION.

(e) Severability. If any term, provision, covenant or restriction of this Agreement is held by a court of competent jurisdiction to be invalid, illegal, void or unenforceable, the remainder of the terms, provisions, covenants and restrictions set forth herein shall remain in full force and effect and shall in no way be affected, impaired or invalidated, and the parties hereto shall use their best efforts to find and employ an alternative means to achieve the same or substantially the same result as that contemplated by such term, provision, covenant or restriction. It is hereby stipulated and declared to be the intention of the parties that they would have executed the remaining terms, provisions, covenants and restrictions without including any of such that may be hereafter declared invalid, illegal, void or unenforceable.

 

-16-


(f) Entire Agreement. This Agreement is intended by the parties as a final expression of their agreement, and is intended to be a complete and exclusive statement of the agreement and understanding of the parties hereto in respect of the subject matter contained herein. There are no restrictions, promises, warranties or undertakings, other than those set forth or referred to herein, with respect to the registration rights granted by the Company with respect to Registrable Common Stock. This Agreement supersedes all prior written or oral agreements and understandings between the parties with respect to such subject matter.

(g) Securities Held by the Company or its Subsidiaries. Whenever the consent or approval of Holders of a specified percentage of Registrable Common Stock is required hereunder, Registrable Common Stock held by the Company or its subsidiaries shall not be counted in determining whether such consent or approval was given by the Holders of such required percentage.

(h) Termination. This Agreement shall terminate when no shares of Registrable Common Stock remain outstanding; provided that Sections 4 and 7 and this Section 14 shall survive any termination hereof.

(i) Specific Performance. The parties hereto recognize and agree that money damages may be insufficient to compensate the Holders of any Registrable Common Stock for breaches by the Company of the terms hereof and, consequently, that the equitable remedy of specific performance of the terms hereof will be available in the event of any such breach.

(j) Effectiveness of Agreement. This Agreement is effective as of the Effective Date. Notwithstanding the foregoing or anything herein to the contrary, if the Convertible Notes Offering is not consummated under the Purchase Agreement for any reason by July 25, 2014 or the Convertible Notes Offering is terminated or abandoned prior to such date, then this Agreement shall be of no force or effect, and the Original Agreement shall continue in full force and effect as if this Agreement had not been entered into.

[Signatures on Following Pages]

 

-17-


EXECUTED and delivered on the date first above written.

 

ENERGY & EXPLORATION PARTNERS, INC.
By:  

/s/ B. Hunt Pettit

Name: B. Hunt Pettit
Title:   President and Chief Executive Officer
H PETTIT HC, INC.
By:  

/s/ B. Hunt Pettit

Name: B. Hunt Pettit
Title:   President and Secretary

Signature Page to Second Amended and Restated Registration Rights Agreement


Oso + Toro Multi Strategy Fund Series Interests of the SALI Multi-Series Fund II 3(c)(1), L.P.
By:   SALI Fund Management, LLC
Its:   Investment Manager
  By:  

/s/ Thomas A. Nieman

  Name: Thomas A. Nieman
  Its:       Chief Financial Officer

Signature Page to Second Amended and Restated Registration Rights Agreement


Oso + Toro Multi Strategy Fund (Tax Exempt) Segregated Portfolio of SALI Multi-Series Fund SPC, Ltd.
By:   SALI Fund Partners, LLC
Its:   General Partner
  By:  

/s/ Thomas A. Nieman

  Name: Thomas A. Nieman
  Its:       Chief Financial Officer

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Carl Lasner

Carl Lasner

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Jason Roberts

Jason Roberts

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Zachary Burk Lowe

Zachary Burk Lowe

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Janice Boswell

Janice Boswell

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Laura Pettit

Laura Pettit

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Matthew F. Ledbetter

Matthew F. Ledbetter

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Amber Boswell

Amber Boswell

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Brian Nelson

Brian Nelson

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ David Patty

David Patty

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Robert Karpman

Robert Karpman

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Tom McNutt

Tom McNutt

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Scott Burk

Scott Burk

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ John Richards

John Richards

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Jim Howe

Jim Howe

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Chase Hanna

Chase Hanna

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Chad Galloway

Chad Galloway

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Lawrence B. Van Ingen

Lawrence B. Van Ingen

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Steve Wilson

Steve Wilson

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Cody Smith

Cody Smith

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ John Foster Pettit, Jr.

John Foster Pettit, Jr.

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Elizabeth Pettit LaVaccare

Elizabeth Pettit LaVaccare

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ Pamela Noelle Pennington

Pamela Noelle Pennington

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ TOM McNUTT

TOM McNUTT, as Trustee of the SYLVIA

SIGNOR FAMILY TRUST

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ TOM McNUTT

TOM McNUTT, as Trustee of the SYLVIA

SIGNOR EDUCATION TRUST

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ BRIAN HUNTLEY PETTIT

BRIAN HUNTLEY PETTIT, as Trustee of the

PETTIT 2012 CHILDREN’S TRUST

Signature Page to Second Amended and Restated Registration Rights Agreement


/s/ BRIAN HUNTLEY PETTIT

BRIAN HUNTLEY PETTIT, as Trustee of the

PETTIT 2012 FAMILY TRUST

Signature Page to Second Amended and Restated Registration Rights Agreement


Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC
By:   Highbridge Principal Strategies Mezzanine Partners II GP, L.P.
Its:   Manager
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Faith Rosenfeld

Name:   Faith Rosenfeld
Title:   Chief Administrative Officer

Signature Page to Second Amended and Restated Registration Rights Agreement


Highbridge Principal Strategies – AP Mezzanine Partners II, L.P.
By:   Highbridge Principal Strategies Mezzanine Partners II GP, L.P.
Its:   General Partner
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Faith Rosenfeld

Name:   Faith Rosenfeld
Title:   Chief Administrative Officer

Signature Page to Second Amended and Restated Registration Rights Agreement


ENXP OFFSHORE, L.P.
By:   Highbridge Principal Strategies Mezzanine Partners II Offshore GP, L.P.
Its:   General Partner
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Faith Rosenfeld

Name:   Faith Rosenfeld
Title:   Chief Administrative Officer

Signature Page to Second Amended and Restated Registration Rights Agreement


ENXP INSTITUTIONAL, L.P.
By:   Highbridge Principal Strategies Mezzanine Partners II Offshore GP, L.P.
Its:   General Partner
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Faith Rosenfeld

Name:   Faith Rosenfeld
Title:   Chief Administrative Officer

Signature Page to Second Amended and Restated Registration Rights Agreement


Apollo Investment Corporation
By:   Apollo Investment Management, L.P.
Its:   Advisor
By:   ACC Management, LLC
Its:   General Partner
By:  

/s/ Ted Goldthorpe

Name:   Ted Goldthorpe
Title:   President

Signature Page to Second Amended and Restated Registration Rights Agreement


Apollo Special Opportunities Managed Account, L.P.
By: Apollo SOMA Advisors, L.P., its General Partner
By: Apollo SOMA Capital Management, LLC, its General Partner
By:  

/s/ Joseph D. Glatt

Name:   Joseph D. Glatt
Title:   Vice President and Assistant Secretary

Signature Page to Second Amended and Restated Registration Rights Agreement


Apollo Centre Street Partnership, L.P.
By:  

Apollo Centre Street Advisors (APO DC), L.P., its General Partner

By:  

Apollo Centre Street Advisors (APO DC-GP), LLC, its General Partner

By:  

/s/ Joseph D. Glatt

Name:   Joseph D. Glatt
Title:   Vice President and Assistant Secretary

Signature Page to Second Amended and Restated Registration Rights Agreement


ANS U.S. Holdings Ltd.
By:  

Apollo SK Strategic Advisors, LLC, its sole director

By:  

/s/ Joseph D. Glatt

Name:   Joseph D. Glatt
Title:   Vice President and Assistant Secretary

Signature Page to Second Amended and Restated Registration Rights Agreement


Exhibit A

HOLDERS

 

          Securities Owned

Holder

  

Address

   Shares of
Common
Stock
     Shares of
Series A
Preferred
Stock
   Shares of
Series B
Preferred
Stock
   Warrants to
Purchase
Series A
Preferred
Stock
   Warrants to
Purchase
Series B
Preferred
Stock

H PETTIT HC, Inc.

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      3               

Oso + Toro Multi Strategy Fund Series Interests of the SALI Multi-Series Fund II 3(c)(1), L.P.

   6836 Austin Center Boulevard, Suite 320, Austin, Texas 78731      56,604               

Oso + Toro Multi Strategy Fund (Tax Exempt) Segregated Portfolio of SALI Multi-Series Fund SPC, Ltd.

   6836 Austin Center Boulevard, Suite 320, Austin, Texas 78731      37,736               

Carl Lasner

   1225 Red Hawk Road, Wimberley, TX 78676      943               

Jason Roberts

   3005 Amherst Avenue, Dallas, TX 75225      5,050               

Zachary Burk Lowe

   4154 Santa Barbara Drive, Dallas, TX 75214      2,358               

Janice Boswell Wueste

   2845 Manorwood Trail, Fort Worth, TX 76109      717               

Laura Pettit

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      360               

Matthew F. Ledbetter

   5309 Judalon Lane, Houston, TX 77056      897               

Amber Boswell

   2721 Manorwood Trail, Fort Worth, TX 76109      8,804               

Brian Nelson

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      50,000               

David Patty

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      25,000               

Robert Karpman

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      15,000               

Tom McNutt

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      10,000               

 

A-1


          Securities Owned

Holder

  

Address

   Shares of
Common
Stock
     Shares of
Series A
Preferred
Stock
   Shares of
Series B
Preferred
Stock
   Warrants to
Purchase
Series A
Preferred
Stock
   Warrants to
Purchase
Series B
Preferred
Stock

Scott Burk

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

Chad Galloway

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      5,000               

Lawrence B. Van Ingen

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

Steve Wilson

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

Cody Smith

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

John Foster Pettit, Jr.

  

P. O. Box 1564

Uvalde, TX 78802

physical:

3102 Eisenhauer #A9

San Antonio, TX 78209

     1,169               

Elizabeth Pettit LaVaccare

  

5540 Millwick Dr.

Alpharetta, GA 30005-2572

     1,169               

Pamela Noelle Pennington

  

1940 Hawthorne Loop

Driftwood, Texas 78619

     1,169               

Sylvia Signor Family Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      4,678               

Sylvia Signor Education Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      9,356               

Pettit 2012 Children’s Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      43,588               

Pettit 2012 Family Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      197,899               

John Richards

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      12,821               

 

A-2


          Securities Owned  

Holder

  

Address

   Shares of
Common
Stock
     Shares of
Series A
Preferred
Stock
   Shares of
Series B
Preferred
Stock
   Warrants to
Purchase
Series A
Preferred
Stock
    Warrants to
Purchase
Series B
Preferred
Stock
 

Jim Howe

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      5,130              

Chase Hanna

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      5,079              

Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              39,018 1      35,630 1 

Highbridge Principal Strategies – AP Mezzanine Partners II, L.P.

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              4,549        4,118   

ENXP Offshore, L.P.

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              63,955        58,396   

ENXP Institutional, L.P.

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              6,864        6,268   

Apollo Investment Corporation

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              60,778     

Apollo Special Opportunities Managed Account, L.P.

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              35,251     

Apollo Centre Street Partnership, L.P.

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              18,233     

ANS U.S. Holdings Ltd.

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              7,293     

 

1  These warrants issued to Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC on April 8, 2013 and March 27, 2014 have been pledged pursuant to that certain Credit Agreement, dated as of December 20, 2012 to which Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC is a party.

 

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Exhibit 4.4

SECOND AMENDED AND RESTATED STOCKHOLDERS AGREEMENT

This Second Amended and Restated Stockholders Agreement (this “Agreement”) is made and entered into as of July 10, 2014 (the “Effective Date”) by and among Energy & Exploration Partners, Inc., a Delaware corporation (the “Company”), and each of the Holders named on Exhibit A hereto. This Agreement amends, restates and replaces in its entirety the Amended and Restated Stockholders Agreement dated as of April 8, 2013 among the Company and the Holders, as amended by the First Amendment thereto dated as of March 26, 2014 (the “Original Agreement”).

WHEREAS, the Company and the Holders desire to set forth their agreement with respect to certain matters relating to the capital stock of the Company and related matters, such that all of the issued and outstanding shares of capital stock of the Company and all outstanding securities exercisable or exchangeable for or convertible into shares of capital stock of the Company (other than the Convertible Notes (as hereinafter defined)), now owned or hereafter acquired, will be subject to this Agreement;

NOW, THEREFORE, in consideration of the premises, the mutual covenants contained herein and other valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree as follows:

1. Definitions. As used in this Agreement, the followings terms have the respective meanings set forth below.

Affiliate” means, with respect to any Person, any other Person directly or indirectly controlling, controlled by or under common control with that Person (with “control” meaning the possession, directly or indirectly, of the power to direct or cause the direction of the management or policies of a Person, whether through the ownership of voting securities, by contract or otherwise).

Apollo” means, collectively, Apollo Investment Corporation, Apollo Special Opportunities Managed Account, L.P., Apollo Centre Street Partnership, L.P. and ANS U.S. Holdings Ltd.

As-Converted Basis” means, at any time, a basis assuming that all Warrants have been exercised and all Shares of Preferred Stock (including Shares of Preferred Stock issuable upon exercise of Warrants) have been converted into Common Stock at the exercise and conversion rates then in effect. For the avoidance of doubt, “As-Converted Basis” shall not give effect to the conversion of any Convertible Notes.

Board” means the Board of Directors of the Company.

Board Observer” has the meaning set forth in Section 7.

Bylaws” means the Bylaws of the Company as in effect from time to time.


Common Stock” means the common stock of the Company, par value $0.01 per share.

Company” has the meaning set forth in the introductory paragraph of this Agreement.

Convertible Notes” means $375 million principal amount of the Company’s 8.0% Convertible Subordinated Notes due 2019 to be issued on or about July 22, 2014 pursuant to an Indenture to be dated as of July 22, 2014 between the Company and U.S. Bank National Association, as trustee.

Convertible Notes Offering” means the initial offering of the Convertible Notes pursuant to the Purchase Agreement.

Covered Person” means officers, members, managers, directors, stockholders, partners, or other interest holders (or any family members of any of the foregoing) of the Company or any of its subsidiaries, in each case, to the extent that such Person owns three percent (3%) or more of the voting Shares of the Company or relevant subsidiary.

Director” means a member of the Board.

Drag-Along Holder” has the meaning set forth in Section 3(a)(i).

Drag-Along Notice” has the meaning set forth in Section 3(a)(ii).

Drag-Along Notice Period” has the meaning set forth in Section 3(a)(iii).

Drag-Along Sale” has the meaning set forth in Section 3(a)(i).

Dragging Holders” has the meaning set forth in Section 3(a)(i).

Effective Date” has the meaning set forth in the introductory paragraph of this Agreement.

Fully Diluted Outstanding” shall means, when used with reference to shares of capital stock of the Company, at any date when the number of shares of capital stock is to be determined, all shares of capital stock of the Company outstanding at such date and all shares of capital stock of the Company issuable upon the exercise, conversion or exchange of any options, warrants or other securities that are directly or indirectly convertible into, or exercisable or exchangeable for, any capital stock of the Company outstanding at such date other than the Convertible Notes.

Fully Exercising Holder” has the meaning set forth in Section 11(b).

GAAP” means generally accepted accounting principles in the United States of America as in effect from time to time.

 

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Highbridge” means, collectively, Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC (“Highbridge Onshore Fund”), Highbridge Principal Strategies – AP Mezzanine Partners II, L.P. ENXP Offshore, L.P., and ENXP Institutional, L.P.

Holder” means any Stockholder or Warrantholder. Exhibit A hereto sets forth the name and address of each Holder and the number of Shares and Warrants held by each Holder. The Company shall revise Exhibit A from time to time to reflect changes in the information set forth thereon, but the failure of the Company so to revise Exhibit A shall not affect the rights and obligations of the Holders and the Company hereunder.

Immediate Family” means, with respect to any individual, that individual’s spouse, parents and lineal descendants (including by adoption) and any trust the sole beneficiaries of which are that individual or any of that individual’s spouse, parents or lineal descendants (including by adoption).

Independent Director” means a Director that is “independent” within the meaning of the rules of the principal national securities exchange on which the Common Stock is listed for trading; provided, that if the Common Stock is not currently trading on a national securities exchange, “Independent Director” shall have the same meaning as “independent director” as defined in the NYSE Listed Company Manual; provided further, that in no event shall any individual who has been employed by the Company or by Encana Corporation on a full-time basis or as a consultant shall be deemed an “Independent Director” for purposes of this Agreement.

Independent Director Requirement” has the meaning set forth in Section 6(c)

Industry Experience” means, when used in reference to any Independent Director, an individual who has at least ten years of service as a director and/or officer of a public company whose primary business is the exploration and production of oil and gas and who has twenty years of experience working in an operational capacity in the oil and gas exploration and production industry.

Major Holder” means, at any time, any Holder that owns, individually or with such Holder’s Affiliates and Immediate Family members, ten percent (10%) or more of the outstanding Shares of Common Stock on an As-Converted Basis.

Necessary Action” means, with respect to a specified result, all actions (to the extent such actions are permitted by law and, in the case of any action by the Company that requires a vote or other action on the part of the Board, to the extent such action is consistent with the fiduciary duties that the Directors may have in such capacity) necessary or desirable to cause such result, including (i) voting or providing a written consent or proxy with respect to Shares of Voting Stock of the Company, (ii) causing the adoption of Stockholders’ resolutions and amendments to the organizational documents of the Company, (iii) executing agreements and instruments, and (iv) making, or causing to be made, with governmental, administrative or regulatory authorities, all filings, registrations or similar actions that are required to achieve such result.

 

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New Securities” has the meaning set forth in Section 11.

Non-Management Majority” has the meaning set forth in Section 7.

Non-Management Holders” means the Holders who are not officers or employees of the Company or Affiliates of officers or employees of the Company; provided, however, that Highbridge and its Affiliates shall not be considered Non-Management Holders for purposes of Section 7 if the right of Highbridge to designate a Director pursuant Section 6(b) is then in effect and Highbridge has exercised such right.

Note Purchase Agreement” means the Note Purchase Agreement, dated as of April 8, 2013, by and among the Company, as Issuer, Cortland Capital Market Services LLC, as administrative agent for the Holders and the Holders named therein, as amended, supplemented or otherwise modified prior to the date hereof.

Offer” has the meaning set forth in Section 2(a).

Offered New Securities” has the meaning set forth in Section 11(a).

Offering Stockholder” has the meaning set forth in Section 2(a).

Offer Notice” has the meaning set forth in Section 11(a).

Offer Period” has the meaning set forth in Section 2(b).

Original Agreement” has the meaning set forth in the introductory paragraph of this Agreement.

Permitted Transfer” means (1) a Transfer pursuant to and in accordance with Section 3; or (2) a Transfer at any time of all or any portion of a Stockholder’s Shares to: (a) any Affiliate of such Stockholder; (b) if such Stockholder is an individual, any members of such Stockholder’s Immediate Family; (c) if such Stockholder is a trust, the beneficiary or beneficiaries thereof; (d) if such Stockholder is an individual, the guardian or legal representative of a Stockholder as to whose estate a guardian or legal representative is appointed and to the executor or administrator of the estate of a deceased Stockholder; or (e) another Stockholder; provided, however, that in each case such Transfer complies with Section 2(f).

Person” means any individual, corporation, general partnership, limited partnership, limited liability partnership, joint venture, association, joint-stock company, trust, limited liability company, unincorporated organization, other entity or government or any agency or political subdivision thereof

 

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Pettit” means B. Hunt Pettit.

Preferred Stock” means the preferred stock of the Company, including the Company’s Series A Preferred Stock and Series B Preferred Stock.

Pro Rata Portion” means, with respect to any Holder at any time, a percentage determined by dividing (i) the number of Shares of Common Stock held by such Holder on an As-Converted Basis by (ii) the number of shares of Common Stock held by all Holders (other than the Offering Stockholder if the Pro Rata Portion is being determined in connection with an Offer) on an As-Converted Basis.

Purchase Agreement” means the Purchase Agreement dated July 10, 2014 between the Company and Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC/Seaport Group Securities, LLC, as representatives of the initial purchasers named therein, with respect to the Convertible Notes.

Purchaser” has the meaning set forth in Section 2(a).

Qualified PO” means the first public offering of the Common Stock (a) in which the aggregate gross proceeds to the Company and the stockholders selling such Common Stock, if any, equal or exceed $400.0 million and (b) following which, such Common Stock is listed on a U.S. national securities exchange. For the avoidance of doubt, if a Qualified PO does not successfully close, it shall not prevent a future public offering from qualifying and being treated as a “Qualified PO.”

Recapitalization” has the meaning set forth in Section 14.

Representatives” has the meaning set forth in Section 15.

Sale of the Company” means the occurrence of (i) the consummation of any stock sale or consolidation, merger, plan of share exchange or other similar transaction involving the Company (any such transaction, a “Change of Control-Sale”) as a result of which the holders of outstanding Voting Stock of the Company immediately prior to the Change of Control-Sale do not continue to hold at least fifty percent (50%) of the combined voting power of the outstanding Voting Stock of the surviving or continuing corporation immediately after the Change of Control-Sale, disregarding any Voting Stock issued or retained by such holders in respect of securities of any other party to the Change of Control-Sale; or (ii) the consummation of any sale, lease, exchange or other transfer (in one transaction or a series of related transactions) of all, or substantially all, the assets of the Company to a third party that is not an Affiliate of the Company.

Securities Act” means the Securities Act of 1933, as amended.

 

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Series A Preferred Stock” means the Series A Mandatorily Convertible Preferred Stock of the Company.

Series A Warrant Shares” means the Shares purchased or, as the context requires, that may be purchased upon the exercise of the Series A Warrants.

Series A Warrants” means warrants issued pursuant to the Note Purchase Agreement and exercisable for Shares of Series A Preferred Stock, any warrants to purchase Shares of Series A Preferred Stock issued upon exchange of Series B Warrants pursuant to the terms of the Series B Warrants and all warrants issued upon permitted Transfer, division or combination of, or in substitution for, any thereof.

Series B Preferred Stock” means the Series B Mandatorily Convertible Preferred Stock of the Company.

Series B Warrant Shares” means the Shares purchased or, as the context requires, that may be purchased upon the exercise of the Series B Warrants.

Series B Warrants” means warrants issued pursuant to the Note Purchase Agreement and exercisable for Shares of Series B Preferred Stock, and all warrants issued upon permitted Transfer, division or combination of, or in substitution for, any thereof.

Shares” means any shares of Common Stock or Preferred Stock.

Significant Holder” means any Holder of Series A Warrants or Series A Warrant Shares that, individually or together with its Affiliates, holds Series A Warrants or Series A Warrant Shares aggregating at least 10% of the Fully Diluted Outstanding Shares.

Significant Holder Majority” means two-thirds of the Shares of Series A Preferred Stock and any Series A Warrants held by Significant Holders and their Affiliates. For purposes of the foregoing, “two-thirds” of such Shares of Series A Preferred Stock and Series A Warrants shall be determined on a basis assuming the exercise of all such Series A Warrants.

Stockholder” means any record holder of Shares.

Tag-Along Holders” has the meaning set forth in Section 3(b)(i).

Tag-Along Notice” has the meaning set forth in Section 3(b)(i).

Tag-Along Notice Period” has the meaning set forth in Section 3(b)(iii).

Tag-Along Right” has the meaning set forth in Section 3(b)(iii).

Tag-Along Response Notice” has the meaning set forth in Section 3(b)(iii).

 

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Tag-Along Sale” has the meaning set forth in Section 3(b)(i).

Tagging Holder” has the meaning set forth in Section 3(b)(i).

Transfer” means, with respect to any Shares or Warrants, any assignment, sale, transfer, conveyance, pledge, grant of an option or other disposition or act of alienation of such Shares or Warrants or of any interest therein, whether voluntary or involuntary or by operation of law.

Voting Stock” means, with respect to any Person, all shares of capital stock of such Person having the right to vote generally in the election of directors of such Person.

Warrantholder” means any record holder of Warrants.

Warrant Shares” means, collectively, the Series A Warrant Shares and Series B Warrant Shares.

Warrants” means, collectively, the Series A Warrants and the Series B Warrants.

2. Restrictions on Transfer; Right of First Refusal.

(a) If any Stockholder (the “Offering Stockholder”) shall at any time propose to make a Transfer of any or all of its Shares other than a Permitted Transfer, the Offering Stockholder shall first make a written offer (an “Offer”) to sell such Shares to the Company and to the other Holders on the same terms. The Offer shall state (i) the name of the proposed third-party transferee (the “Purchaser”), (ii) the number of Shares proposed to be transferred and the purchase price and payment terms for the offered Shares, and (iii) all other terms and conditions of the proposed Transfer (which shall be based upon bona fide good faith terms and conditions). The terms of the proposed Transfer shall be of a conventional nature and shall not include value for personal services or other unique consideration which would be difficult for the Company and the other Holders to duplicate. In addition, the Offer shall be made without regard to the requirement of any earnest money or similar deposit required of the Purchaser prior to closing, and without regard to any security (other than the offered Shares) to be provided by the Purchaser for any deferred portion of the purchase price.

(b) The Offer shall be irrevocable for a period (the “Offer Period”) ending at 11:59 p.m. (local time at the Company’s principal office) on the 60th day following the date of delivery of the Offer to the Company and the other Holders (or if delivery of the Offer is not made to all such Persons on the same day, on the 60th day following the latest date of delivery of the Offer to any such Person).

(c) Subject to the consent rights set forth in Section 12(a) and in the Certificate of Designations of the Series A Preferred Stock, at any time during the first 30 days of the Offer Period, the Company may accept the Offer in its entirety by giving written notice to all Holders of its decision to accept the Offer. If the Company does not accept the Offer as to all of the offered Shares within such 30-day period, the Company shall promptly give all Holders

 

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written notice of its failure to accept the Offer and, regardless of whether such notice is given by the Company, any Holder (other than the Offering Stockholder) may accept the Offer as to its Pro Rata Portion of the offered Shares, by giving written notice of such acceptance to the Offering Stockholder on or before the expiration of the Offer Period. In addition, any Holder may indicate in its notice a desire to purchase a greater number of Shares in the event one or more other Holders fails or chooses not to exercise its option to purchase, and such additional Shares shall be allocated among the Holders who have indicated a desire to purchase a greater number of Shares on a pro rata basis or any other basis mutually acceptable to such Holders. In the event that the Holders accepting the Offer, in the aggregate, accept the Offer with respect to all of the offered Shares, the Offer shall be deemed to be accepted. If neither the Company nor the Holders accept the Offer as to all of the offered Shares during the Offer Period, the Offer shall be deemed to be rejected in its entirety.

(d) In the event that the Offer is accepted, the closing of the Transfer of the offered Shares shall take place within 30 days after the Offer is accepted or, if later, the date of closing set forth in the Offer. The Offering Stockholder, the Company and the electing Holders, if applicable, shall execute such documents and instruments as may be necessary or appropriate to effect the Transfer of the offered Shares pursuant to the terms of the Offer and this Section 2.

(e) If the Offer is not accepted in the manner provided hereinabove, the Offering Stockholder may transfer the offered Shares to the Purchaser specified in the Offer at any time within 60 days after the last day of the Offer Period, provided that such transfer shall be made on terms no more favorable to the Purchaser than the terms contained in the Offer and provided further that the Purchaser agrees to be bound by the terms and provisions of this Agreement. In the event that the offered Shares are not transferred in accordance with the terms of the preceding sentence, the offered Shares shall again become subject to all of the conditions and restrictions of this Section 2.

(f) Notwithstanding anything herein to the contrary, no Transfer, including a Permitted Transfer, shall be permitted unless and until the following conditions are satisfied; provided, however, that any such conditions may be waived in writing by the Board:

(i) Except in the case of a Transfer involuntarily by operation of law, the transferor and transferee shall execute and deliver to the Company such documents and instruments of conveyance as may be necessary or appropriate in the reasonable opinion of counsel to the Company to effect such Transfer, or in the case of a Transfer of Warrants, as provided in the Warrants. In the case of a Transfer involuntarily by operation of law, the Transfer shall be confirmed by presentation to the Company of legal evidence of such Transfer, in form and substance reasonably satisfactory to counsel to the Company. In all cases, the Company shall be reimbursed by the transferor and/or transferee for all costs and expenses that it reasonably incurs in connection with such Transfer.

(ii) The transferor and transferee shall furnish the Company with the transferee’s taxpayer identification number and any other information reasonably necessary to

 

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permit the Company to file all required federal, state, and local tax returns and other legally required information statements or returns. Without limiting the generality of the foregoing, the Company shall not be required to make any dividends or other distributions with respect to any transferred Shares until it has received such information.

(iii) The transferee shall execute and deliver to the Company a counterpart of this Agreement or other writing reasonably satisfactory to the Company evidencing that the transferee has become a party to this Agreement and that the Shares or Warrants owned by the transferee are subject to the applicable restrictions of this Agreement.

(iv) Except in the case of a Transfer of Shares or Warrants involuntarily by operation of law, either (x) such Shares or Warrants shall be registered under the Securities Act, and any applicable state securities laws or (y) the transferor shall provide an opinion of counsel, at transferor’s expense, which opinion and counsel shall be reasonably satisfactory to the Company, to the effect that such Transfer is exempt from all applicable registration requirements and that such Transfer will not violate any applicable laws regulating the transfer of securities.

(g) Any Transfer made or purported to be made in contravention of this Section 2 shall be void and of no force or effect and shall not be recognized by the Company.

(h) The Transfer of Warrants shall be subject to the transfer restrictions set forth in the Warrants and Sections 2(f) and 2(g) of this Agreement but shall not be subject to the provisions of Sections 2(a) through 2(e) of this Agreement.

3. Drag Along/Tag Along Rights.

(a) (i) In the event Holders holding greater than seventy-five percent (75%) of the outstanding Shares of Common Stock on an As-Converted Basis (the “Dragging Holders”) propose to sell, in any transaction or series of related transactions, all of their Shares and Warrants other than to a Person described in clauses (a)-(d) of clause (2) of the definition of Permitted Transfer in Section 1 (a “Drag-Along Sale”), the Dragging Holders shall have the right, at their option, to require all, but not less than all, of the other Holders (each, a “Drag-Along Holder”) to sell all of their Shares and Warrants in such Drag-Along Sale.

(ii) The Dragging Holders shall provide each Drag-Along Holder notice of the terms and conditions of such proposed Transfer (the “Drag-Along Notice”) not later than twenty (20) business days prior to the closing of the proposed Drag-Along Sale. The Drag-Along Notice shall identify the consideration for which the Transfer is proposed to be made, and all other material terms and conditions of the Drag-Along Sale, including the form of the proposed agreement, if any. Each Drag-Along Holder shall be required to participate in the Drag-Along Sale on the terms and conditions set forth in the Drag-Along Notice.

(iii) Within ten (10) business days following the date of the Drag-Along Notice (the “Drag-Along Notice Period”), each Drag-Along Holder must deliver to the Dragging

 

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Holders (i) wire transfer instructions for payment of the purchase price for the Shares or Warrants to be sold in such Drag-Along Sale, (ii) a limited power-of-attorney authorizing the Dragging Holders to transfer such Shares or Warrants on the terms set forth in the Drag-Along Notice, and (iii) all other documents required to be executed in connection with such Drag-Along Sale. If any Drag-Along Holder fails to deliver any such documents, the Company shall cause the books and records of the Company to show that such Drag-Along Holder is bound by the provisions of this Section 3(a) and that the Shares or Warrants of such Drag-Along Holder shall be transferred to the acquiring party immediately upon surrender for transfer by the Drag-Along Holder thereof.

(iv) If, at the end of a 90-day period after the date on which the Dragging Holders give the Drag-Along Notice (which 90-day period shall be extended if any of the transactions contemplated by the Drag-Along Sale are subject to regulatory approval until the expiration of five business days after all such approvals have been received, but in no event later than 120 days following the delivery of the Drag-Along Notice), the Drag-Along Sale has not been completed on substantially the same terms and conditions set forth in the Drag-Along Notice, the Drag-Along Holders shall no longer be obligated to sell their Shares or Warrants pursuant to such Drag-Along Notice and the Dragging Holders shall return to each Drag-Along Holder the limited power-of-attorney (and all copies thereof) that such Drag-Along Holder delivered for transfer pursuant to this Section 3(a) and any other documents in the possession of the Dragging Holders executed by such Drag-Along Holder in connection with the proposed Drag-Along Sale.

(v) Concurrently with the consummation of the Drag-Along Sale, the Dragging Holders shall (A) notify the Drag-Along Holders thereof, (B) remit to the Drag-Along Holders the total consideration for the Shares or Warrants of the Drag-Along Holders transferred pursuant thereto, and (C) promptly after the consummation of the Drag-Along Sale, furnish such other evidence of the completion and the date of completion of such Transfer and the terms thereof as may be reasonably requested by the Drag-Along Holders.

(vi) Notwithstanding anything contained in this Section 3(a), there shall be no liability on the part of the Dragging Holders to the Drag-Along Holders if the Transfer of the Shares and Warrants pursuant to this Section 3(a) is not consummated for any reason.

(vii) Notwithstanding anything contained in this Section 3(a), the obligations of the Drag-Along Holders to participate in a Drag-Along Sale are subject to the following conditions:

(A) upon the consummation of such Drag-Along Sale, all of the Holders participating therein will receive the same form of consideration and shall be subject to all of the same other terms and conditions of such sale (and no such terms and conditions shall be less favorable to the Drag-Along Holders than to the Dragging Holders) in a manner proportionate to their relative number of Shares (on as As-Converted Basis) being sold; provided, however, that, with respect to any Warrants or Shares of Preferred Stock included in a Drag-Along Sale, the consideration payable in

 

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respect of such Warrants or Shares shall be the amount of consideration payable in respect of the number of Shares of Common Stock issuable upon the exercise of such Warrants and conversion of such Shares of Preferred Stock and the Shares of Preferred Stock issuable upon the exercise of such Warrants, less, in the case of Warrants, the aggregate exercise price of such Warrants; and provided, further, that each Drag-Along Holder shall only be obligated to make individual representations and warranties with respect to its title to and ownership of the applicable Shares or Warrants, authorization, execution and delivery of relevant documents, enforceability of such documents against the Drag-Along Holder, and other matters relating to such Drag-Along Holder, but not with respect to any of the foregoing with respect to any other Holders or their Shares or Warrants; and provided, further, that all representations, warranties, covenants and indemnities shall be made by each of the Dragging Holders and each Drag-Along Holder severally and not jointly and any indemnification obligation shall be pro rata based on the consideration received by each of the Dragging Holders and each Drag-Along Holder, in each case in an amount not to exceed the aggregate proceeds received by such Dragging Holder or Drag-Along Holder, as applicable, in connection with the Drag-Along Sale; and

(B) no Drag-Along Holder participating therein shall be obligated to pay any expenses incurred in connection with any unconsummated Drag-Along Sale, and each Holder shall be obligated to pay only its pro rata share (based on the relative number of Shares (on an As-Converted Basis) being sold) of expenses incurred in connection with a consummated Drag-Along Sale to the extent such expenses are incurred for the benefit of all Holders and are not otherwise paid by the Company or another Person.

(b) (i) In the event that Holders holding greater than fifty percent (50%) of the outstanding Shares of Common Stock on an As-Converted Basis (the “Tag-Along Holders”) propose to sell, in any transaction or series of related transactions, all or substantially all of their Shares and Warrants other than to a Person described in clauses (a)-(d) of clause (2) of the definition of Permitted Transfer in Section 1 (a “Tag-Along Sale”), and in the case of a Drag-Along Sale, the Tag-Along Holders do not exercise their rights under Section 3(a), (A) the Tag-Along Holders shall provide each other Holder notice of the terms and conditions of such proposed Transfer (the “Tag-Along Notice”) and offer each other Holder the opportunity to participate in such Transfer in accordance with this Section 3(b), such Tag-Along Notice to be provided not later than twenty (20) business days prior to the closing of the proposed Tag-Along Sale, and (B) each other Holder may elect, at its option, to participate in the proposed transfer in accordance with this Section 3(b) (each such electing Holder, a “Tagging Holder”).

(ii) The Tag-Along Notice shall identify the consideration for which the Transfer is proposed to be made, and all other material terms and conditions of the Tag-Along Sale, including the form of the proposed agreement, if any.

(iii) From the date of its receipt of the Tag-Along Notice, each Tagging Holder shall have the right (a “Tag-Along Right”), exercisable by notice (the “Tag-Along Response Notice”) given to the Tag-Along Holders within ten (10) business days after its receipt of the

 

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Tag-Along Notice (the “Tag-Along Notice Period”), to request that the Tag-Along Holders include in the proposed sale the Shares and Warrants held by such Tagging Holder, and the Tag-Along Holders shall not be allowed to sell any of their Shares or Warrants in the proposed sale without the simultaneous sale of all Shares and Warrants elected to be included by such Tagging Holder in accordance with this Section 3(b).

(iv) Each Tag-Along Response Notice shall include wire transfer instructions for payment of the purchase price for the Shares or Warrants to be sold in such Tag-Along Sale. Each Tagging Holder that exercises its Tag-Along Rights hereunder shall deliver to the Tag-Along Holders, with its Tag-Along Response Notice, a limited power-of-attorney authorizing the Tag-Along Holders to transfer its Shares or Warrants on the terms set forth in the Tag-Along Notice and all other documents required to be executed in connection with such Tag-Along Sale. Delivery of the Tag-Along Response Notice with such limited power-of-attorney shall constitute an irrevocable acceptance of the terms of the Tag-Along Sale by such Tagging Holder.

(v) If, at the end of a 90-day period after delivery of the Tag-Along Response Notice (which 90-day period shall be extended if any of the transactions contemplated by the Tag-Along Sale are subject to regulatory approval until the expiration of five business days after all such approvals have been received, but in no event later than 120 days following receipt by the Tag-Along Holders of the Tag-Along Response Notice), the Tag-Along Holders have not completed the transfer of their Shares or Warrants, along with any Shares or Warrants being sold by any Tagging Holder, on substantially the same terms and conditions set forth in the Tag-Along Notice, the Tag-Along Holders shall (i) return to each Tagging Holder the limited power-of-attorney (and all copies thereof) that such Tagging Holder executed and any other documents in the possession of the Tag-Along Holders executed by the Tagging Holders in connection with the proposed Tag-Along Sale, and (ii) not conduct any transfer of their Shares or Warrants without again complying with this Section 3(b).

(vi) Concurrently with the consummation of the Tag-Along Sale, the Tag-Along Holders shall (i) notify the Tagging Holders thereof, (ii) remit to the Tagging Holders the total consideration for the Shares or Warrants of the Tagging Holders transferred pursuant thereto, and (iii) promptly after the consummation of the Tag-Along Sale, furnish such other evidence of the completion and the date of completion of such Transfer and the terms thereof as may be reasonably requested by the Tagging Holders.

(vii) If at the termination of the Tag-Along Notice Period any Holder shall not have elected to participate in the Tag-Along Sale, such Holder shall be deemed to have waived its rights under this Section 3(b) with respect to the Transfer of its Shares or Warrants pursuant to such Tag-Along Sale.

(viii) Notwithstanding anything contained in this Section 3(b), there shall be no liability on the part of the Tag-Along Holders to the Tagging Holders if the transfer of the Shares and Warrants pursuant to this Section 3(b) is not consummated for whatever reason, provided that the Tagging Holders have complied with their notice and other obligations under this Section 3(b). Whether to effect a transfer of Shares or Warrants by the Tag-Along Holders is in the sole and absolute discretion of the Tag-Along Holders.

 

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(ix) Notwithstanding anything contained in this Section 3(b), the rights and obligations of the Holders to participate in a Tag-Along Sale are subject to the following conditions:

(A) upon the consummation of such Tag-Along Sale, all of the Holders participating therein will receive the same form of consideration and shall be subject to all of the same other terms and conditions of such sale (and no such terms and conditions shall be less favorable to the Tagging Holders than to the Tag-Along Holders) in a manner proportionate to their relative Shares (on an As-Converted Basis) being sold; provided, however, that, with respect to any Warrants or Shares of Preferred Stock included in a Tag-Along Sale, the consideration payable in respect of such Warrants or Shares shall be the amount of consideration payable in respect of the number of Shares of Common Stock issuable upon the exercise of such Warrants and conversion of such Shares of Preferred Stock and the Shares of Preferred Stock issuable upon the exercise of such Warrants, less, in the case of Warrants, the aggregate exercise price of such Warrants; and provided, further, that each Tagging Holder shall only be obligated to make individual representations and warranties with respect to its title to and ownership of the applicable Shares or Warrants, authorization, execution and delivery of relevant documents, enforceability of such documents against the Tagging Holder, and other matters relating to such Tagging Holder, but not with respect to any of the foregoing with respect to any other Holders or their Shares or Warrants; and provided, further, that all representations, warranties, covenants and indemnities shall be made by each of the Tag-Along Holders and each Tagging Holder severally and not jointly and any indemnification obligation shall be pro rata based on the consideration received by each of the Tag-Along Holders and each Tagging Holder, in each case in an amount not to exceed the aggregate proceeds received by such Tag-Along Holder or Tagging Holder, as applicable, in connection with the Tag-Along Sale; and

(B) no Tagging Holder participating therein shall be obligated to pay any expenses incurred in connection with any unconsummated Tag-Along Sale, and each Holder shall be obligated to pay only its pro rata share (based on the relative number of Shares (on an As-Converted Basis) transferred) of expenses incurred in connection with a consummated Tag-Along Sale to the extent such expenses are incurred for the benefit of all such Holders and are not otherwise paid by the Company or another Person.

4. Legend. Upon the issuance of certificates representing the Shares or Warrants subject to this Agreement, the Company shall endorse a legend in substantially the following form on such certificates:

THE SECURITIES REPRESENTED BY THIS CERTIFICATE HAVE NOT BEEN REGISTERED UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), OR ANY STATE SECURITIES OR “BLUE SKY” LAWS.

 

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THEY MAY NOT BE OFFERED, SOLD, TRANSFERRED, ASSIGNED, PLEDGED OR HYPOTHECATED, IN THE ABSENCE OF AN EFFECTIVE REGISTRATION STATEMENT FOR THE SECURITIES UNDER THE SECURITIES ACT OR UNLESS THE COMPANY HAS RECEIVED AN OPINION OF COUNSEL REASONABLY SATISFACTORY TO THE COMPANY THAT SUCH REGISTRATION IS NOT REQUIRED.

ANY SALE, TRANSFER, ASSIGNMENT, PLEDGE, ENCUMBRANCE OR DISPOSITION OF THE SECURITIES REPRESENTED BY THIS CERTIFICATE OR ANY INTEREST THEREIN IS SUBJECT TO THE TERMS AND PROVISIONS OF THE SECOND AMENDED AND RESTATED STOCKHOLDERS AGREEMENT DATED AS OF JULY 10, 2014, BY AND AMONG THE COMPANY AND ITS STOCKHOLDERS AND WARRANTHOLDERS, A COPY OF WHICH IS ON FILE WITH SECRETARY OF THE COMPANY.

The fact that this legend may not appear on any stock certificate or warrant certificate shall not in any way affect the validity, force or effect of this Agreement.

5. Stop-Transfer. The Company shall not effect any transfer of Shares or Warrants on its books and records until it has received evidence reasonably satisfactory to it that the terms of this Agreement applicable to such transfer have been complied with and until the transferee signs a counterpart of this Agreement agreeing to be bound by the terms and provisions hereof.

6. Board Composition.

(a) Commencing on the date hereof, the Board shall consist of seven Directors, as set from time to time by the Board as provided in the Bylaws. The Company (x) will not decrease the number of Directors below four or increase the number of Directors above seven without the consent of Pettit (so long as Pettit and his Affiliates and members of his Immediate Family hold in the aggregate 20% or more of the outstanding Shares of Common Stock on an As-Converted Basis) and (y) will not decrease the number of Directors below seven without the consent of Highbridge so long as Highbridge and its Affiliates hold any Convertible Notes. As of the date hereof, the Board consists of the individuals named on Exhibit B attached hereto.

(b) So long as Highbridge and its Affiliates (other than ENXP Offshore, L.P.) hold in the aggregate 10% or more of the outstanding Shares of Common Stock on an As-Converted Basis, Highbridge Onshore Fund shall have the right to designate one Director. For the avoidance of doubt, in no event shall ENXP Offshore, L.P. have any right to participate in the designation of such Director.

(c) So long as Pettit remains the President or Chief Executive Officer of the Company, Pettit shall be a Director and shall be Chairman of the Board. In addition, so long as

 

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Pettit and his Affiliates and members of his Immediate Family hold in the aggregate 20% or more of the outstanding Shares of Common Stock on an As-Converted Basis, Pettit shall have the right to designate all of the Directors other than any Director designated by Highbridge pursuant to Section 6(b). Notwithstanding the foregoing, for so long as (i) Highbridge or Apollo is a Significant Holder and (ii) Highbridge, Apollo and their respective Affiliates collectively purchase at least $50 million principal amount of Convertible Notes in the Convertible Notes Offering and continue to hold at least $50 million principal amount of Convertible Notes, one of the Directors designated by Pettit pursuant to this Section 6(c) shall be an Independent Director with Industry Experience (the “Independent Director Requirement”). If the Independent Director Requirement is applicable, an Independent Director designated pursuant to such requirement shall be elected to the Board promptly, but in no circumstances later than two months after the pricing of the Convertible Notes Offering.

(d) The Company shall take all Necessary Action to cause the individuals designated in accordance with Sections 6(b) and 6(c) to be elected to the Board, including without limitation soliciting proxies in favor thereof if proxies are solicited for the election of Directors and, in connection with each meeting of the Stockholders at which directors of the Company are to be elected and any action by written consent to elect Directors, recommending that the Stockholders elect to the Board each such individual.

(e) At each election of Directors held after the date hereof (or each written consent in lieu thereof), each Holder (except as provided in Section 6(i)) agrees to vote all shares of Voting Stock of the Company entitled to vote in the election of Directors owned or held of record by such Holder, and to take any other Necessary Actions, to elect (or to execute such written consent consenting to the election of) the individuals designated in accordance with Sections 6(b) and 6(c) as Directors. The voting agreements contained in this Section 6 are coupled with an interest and may not be revoked or amended except as set forth in this Agreement.

(f) If Highbridge or Pettit provides written notice to each other Holder entitled to vote in the election of Directors indicating that Highbridge or Pettit, as applicable, desires to remove a Director previously designated by such Person pursuant to Section 6(b) or 6(c), then such Director shall be removed, and each Holder (except as provided in Section 6(i)) hereby agrees to vote all shares of Voting Stock of the Company owned or held of record by such Holder to effect such removal. Notwithstanding the foregoing, (i) no Director designated by Highbridge shall be removed, with or without cause, without the prior written consent of Highbridge, and no Director designated by Pettit shall be removed, with or without cause, without the prior written consent of Pettit, and (ii) if the Independent Director Requirement is then applicable, no Director designated by Pettit pursuant to such Independent Director Requirement shall be removed unless such Director is contemporaneously replaced with a new Director designated pursuant to the Independent Director Requirement.

(g) If a vacancy is created on the Board at any time by the death, disability, retirement, resignation or removal (with or without cause) of a Director designated pursuant to Section 6(b) or 6(c), the Person who previously designated such Director shall be entitled to designate a replacement Director to fill such vacancy, and each Holder (except as provided in

 

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Section 6(i)) then entitled to vote in the election of Directors hereby agrees to vote all shares of Voting Stock of the Company owned or held of record by it for the individual designated to fill such vacancy by Highbridge or Pettit, as applicable; provided, that such designee may not previously have been a Director who was removed for cause; and provided further that, if the Independent Director Requirement is then applicable and the vacancy resulted from the death, disability, retirement, resignation or removal (with or without cause) of a Director designated by Pettit and designated pursuant to the Independent Director Requirement, the Independent Director Requirement shall apply to the filling of such vacancy.

(h) Notwithstanding the foregoing, this Section 6 confers upon Highbridge and Pettit the right, but not the obligation, to designate Directors, and Highbridge or Pettit may, at its option, elect not to exercise any such right to designate Directors; provided that no election by Highbridge or Pettit to refrain from exercising any such right shall in any way affect such right or any Holder’s obligations under this Agreement.

(i) Notwithstanding anything herein to the contrary, the requirements to vote shares of Voting Stock of the Company contained in this Section 6 shall not apply to Oso + Toro Multi Strategy Fund Series Interests of the SALI Multi-Series Fund II 3(c)(1), L.P., Oso + Toro Multi Strategy Fund (Tax Exempt) Segregated Portfolio of SALI Multi-Series Fund SPC, Ltd. or any of their Affiliates.

7. Board Observer Right. The Non-Management Holders may, by a written instrument executed by the Non-Management Holders holding a majority of the Shares held by all Non-Management Holders on an As-Converted Basis (a “Non-Management Majority”), designate one individual to attend meetings of the Board and receive related materials as an observer (the “Board Observer”); provided, however, that the Board Observer shall only be allowed to observe meetings of the full Board and of the Board’s executive committee or other committee serving a similar function (and not any meetings of any other Board committee), and the Board Observer shall in no circumstances have any right to participate in any vote, consent or other action of the Board or any committee thereof; and provided, further, that the Board Observer may be excluded from any Board meeting or portion thereof and may be prohibited from receiving any related materials (i) if the Board determines in good faith that such exclusion is necessary to preserve attorney-client, work product or similar privilege, to comply with the terms and conditions of confidentiality agreements with third parties, or to comply with applicable law, or (ii) if the Board determines in good faith that there exists, with respect to the subject matter of a Board meeting or related materials, an actual or potential conflict of interest between the Board Observer or any Affiliate of the Board Observer and the Company.

8. Director Nomination Rights Following Qualified PO.

(a) Following the consummation of a Qualified PO and until such time as the Board nomination rights set forth in both Sections 8(b) and 8(c) are no longer in effect, the Board shall at all times consist of the number of Directors that Highbridge and Pettit are entitled to nominate pursuant to Sections 8(b) and 8(c) plus such number of additional Directors that are Independent Directors as may be required by the rules of the principal national securities exchange on which

 

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the Common Stock is listed for trading. The Company will not decrease or increase the number of Directors to a number less than or greater than the number of Directors specified in this Section 8(a) without the consent of the Highbridge (so long as Highbridge and its Affiliates hold in the aggregate 10% or more of the outstanding Shares of Common Stock) and Pettit (so long as Pettit and his Affiliates and members of his Immediate Family hold in the aggregate 10% or more of the outstanding Shares of Common Stock).

(b) So long as Highbridge and its Affiliates hold in the aggregate 10% or more of the outstanding Shares of Common Stock, Highbridge shall have the right to nominate one Director.

(c) So long as Pettit and his Affiliates and members of his Immediate Family hold in the aggregate 10% or more of the outstanding Shares of Common Stock, Pettit shall have the right to nominate the following number of Directors:

(i) Three Directors, so long as Pettit and his Affiliates and members of his Immediate Family hold in the aggregate 20% or more of the outstanding Shares of Common Stock;

(ii) Two Directors, so long as Pettit and his Affiliates and members of his Immediate Family hold in the aggregate 15% or more of the outstanding Shares of Common Stock; and

(iii) One Director, so long as Pettit and his Affiliates and members of his Immediate Family hold in the aggregate 10% or more of the outstanding Shares of Common Stock.

(d) Upon consummation of a Qualified PO, the Board shall be divided, with respect to the time for which Directors severally hold office, into three classes of Directors, as nearly equal in number as is reasonably possible, with the initial term of office of the first class to expire at the first annual meeting of stockholders of the Company following the consummation of a Qualified PO, the initial term of office of the second class to expire at the second annual meeting of stockholders of the Company following the consummation of a Qualified PO, and the initial term of office of the third class to expire at the third annual meeting of stockholders of the Company following the consummation of a Qualified PO. The Directors shall be allocated among the three classes of Directors as follows: (i) so long as Highbridge has the right to nominate a Director pursuant to Section 8(b), the Director position for which Highbridge is entitled to nominate a Director shall be in the third class of Directors referred to above, (ii) so long as Pettit is entitled to nominate three Directors pursuant to Section 8(c), one Director position for which Pettit is entitled to nominate a Director shall be in each of the first, second and third classes of Directors referred to above; (iii) so long as Pettit is entitled to nominate two Directors pursuant to Section 8(c), one Director position for which Pettit is entitled to nominate a Director shall be in each of the second and third classes of Directors referred to above; (iv) so long as Pettit is entitled to nominate one Director pursuant to Section 8(c), the Director position for which Pettit is entitled to nominate a Director shall be in the third class of Directors referred to above; and (v) the Independent Directors shall be allocated among the classes of Directors in such a manner as to make the classes of Directors as nearly equal in number as is reasonably possible.

 

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(e) The Company shall cause the individuals designated in accordance with Sections 8(b) and 8(c) to be nominated for election to the Board, shall solicit proxies in favor thereof, and at each meeting of the stockholders of the Company at which Directors are to be elected, shall recommend that the stockholders of the Company elect to the Board each such individual nominated for election at such meeting.

(f) At each election of Directors held in connection with or after the date of the consummation of a Qualified PO (or each written consent in lieu thereof), each of Pettit, Highbridge and each Holder that is an Affiliate of Pettit or Highbridge agrees to vote all shares of Voting Stock of the Company entitled to vote in the election of Directors owned or held of record by such Holder, and to take any other Necessary Actions, to elect (or to execute such written consent consenting to the election of) the nominees designated pursuant to Sections 8(b) and 8(c). The voting agreements contained in this Section 8 are coupled with an interest and may not be revoked or amended except as set forth in this Agreement.

(g) If Highbridge or Pettit provides written notice to the other indicating that Highbridge or Pettit, as applicable, desires to remove a Director previously nominated by such Person pursuant to Section 8(b) or 8(c), then such Director shall be removed, and each of Pettit, Highbridge and each Holder that is an Affiliate of Pettit or Highbridge hereby agrees to vote all shares of Voting Stock of the Company owned or held of record by such Holder to effect such removal. Notwithstanding the foregoing, no Director nominated by Highbridge shall be removed, with or without cause, without the prior written consent of Highbridge, and no Director nominated by Pettit shall be removed, with or without cause, without the prior written consent of Pettit.

(h) If a vacancy is created on the Board at any time by the death, disability, retirement, resignation or removal (with or without cause) of a Director nominated pursuant to Section 8(b) or 8(c), the Person who previously nominated such Director shall be entitled to nominate a replacement Director to fill such vacancy, and each of Pettit, Highbridge and each Holder that is an Affiliate of Pettit or Highbridge hereby agrees to vote all shares of Voting Stock of the Company owned or held of record by it for the individual nominated to fill such vacancy by Highbridge or Pettit, as applicable; provided, that such designee may not previously have been a Director who was removed for cause.

(i) Notwithstanding the foregoing, this Section 8 confers upon Highbridge and Pettit the right, but not the obligation, to nominate Directors, and Highbridge or Pettit may, at its option, elect not to exercise any such right to nominate Directors; provided that no election by Highbridge or Pettit to refrain from exercising any such right shall in any way affect such right or any Holder’s obligations under this Agreement.

9. Limitation on Share Awards. After the date hereof and prior to the consummation of a Qualified PO, the Company shall not grant any award of Shares, or rights or options with

 

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respect to Shares, to any officer, director, employee or consultant of the Company or any of its subsidiaries without the prior approval of a Non-Management Majority; provided, however, that the Company may grant such awards with respect to an aggregate number of Shares that does not exceed 15% of the Fully Diluted Outstanding Shares of the Company as of the date hereof. For the avoidance of doubt, the foregoing shall not prohibit any such awards made in connection with and substantially contemporaneously with the consummation of a Qualified PO.

10. Information Rights.

(a) The Company shall deliver to each Major Holder:

(i) as soon as practicable, but in any event within ninety (90) days after the end of each fiscal year of the Company, (i) a balance sheet as of the end of such year, (ii) statements of income and of cash flows for such year, and (iii) a statement of stockholders’ equity as of the end of such year, all such financial statements audited by independent public accountants selected by the Board; and

(ii) as soon as practicable, but in any event within forty-five (45) days after the end of each of the first three (3) quarters of each fiscal year of the Company, unaudited statements of income and of cash flows for such fiscal quarter and the year to date, and an unaudited balance sheet as of the end of such fiscal quarter, all prepared in accordance with GAAP (except that such financial statements may (i) be subject to normal year-end audit adjustments and (ii) not contain all notes thereto that may be required in accordance with GAAP).

If the Company has any subsidiaries, the obligation of the Company to deliver information as set forth in this Section 10(a) shall be construed to include the equivalent information concerning each of its subsidiaries, which, if required or appropriate under GAAP, may be delivered on a consolidated basis. Notwithstanding anything else in this Section 10(a) to the contrary, the Company may cease providing the information set forth in this Section 10(a) during the period starting with the date sixty (60) days before the good-faith estimate of the Board of the date of filing of a registration statement if it reasonably concludes it must do so to comply with the Securities and Exchange Commission rules applicable to such registration statement and related offering; provided that the Company’s covenants under this Section 10(a) shall be reinstated at such time as the Company is no longer actively employing its commercially reasonable efforts to cause such registration statement to become effective.

(b) The Company shall permit each Major Holder or its representatives, at such Major Holder’s expense, to visit and inspect the Company’s properties, examine its books of account and records and discuss the Company’s affairs, finances and accounts with the Company’s officers, during normal business hours of the Company as may be reasonably requested by the Major Holder; provided, however, that the Company shall not be obligated pursuant to this Section 10(b) to provide access to any information that it reasonably considers to be a trade secret or confidential information (unless covered by an enforceable confidentiality agreement, in form acceptable to the Company) or the disclosure of which would adversely affect the attorney-client privilege between the Company and its counsel.

 

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11. Rights to Future Stock Issuances. Subject to the terms and conditions of this Section 11 and applicable securities laws, if the Company proposes to offer or sell any (i) equity securities of the Company, whether or not currently authorized, (ii) rights, convertible securities, options, or warrants to purchase or otherwise acquire such equity securities of the Company, or (iii) securities of any type whatsoever that are, or may become, convertible or exchangeable into or exercisable for equity securities of the Company, including, without limitation, convertible debt (collectively, “New Securities”), the Company shall first offer such New Securities to each Stockholder, as follows:

(a) The Company shall give written notice (the “Offer Notice”) to each Holder, stating (i) its bona fide intention to offer such New Securities, (ii) the total number of such New Securities to be offered (the “Offered New Securities”), and (iii) the price and terms upon which it proposes to offer such New Securities.

(b) By notification to the Company within fifteen (15) days after the Offer Notice is received, each Holder may elect to purchase or otherwise acquire, at the price and on the terms specified in the Offer Notice, up to its Pro Rata Portion of the Offered New Securities. At the expiration of such fifteen (15) day period, the Company shall promptly notify each Holder that elects to purchase or acquire all the shares available to it (each, a “Fully Exercising Holder”) of any Holder’s failure to do likewise. During the fifteen (15) day period commencing on the date of delivery of such notice, each Fully Exercising Holder may, by giving notice to the Company, elect to purchase or acquire, in addition to the number of Offered New Securities specified above, up to that portion of the Offered New Securities for which Holders were entitled to subscribe but that were not subscribed for by the Holders which is equal to the proportion that the number of Shares of Common Stock then held by such Fully Exercising Holder on an As-Converted Basis immediately prior to the issuance of the Offered New Securities bears to the total number of Shares of Common Stock then held immediately prior to the issuance of New Securities by all Fully Exercising Holders who wish to purchase or otherwise acquire such unsubscribed shares on an As-Converted Basis. The closing of any sale pursuant to this Section 11(b) shall occur within the later of ninety (90) days of the date that the Offer Notice is given and the date of initial sale of Offered New Securities pursuant to Section 11(c).

(c) If all Offered New Securities referred to in the Offer Notice are not elected to be purchased or acquired as provided in Section 11(b), the Company may, during the ninety (90) day period following the expiration of the periods provided in Section 11(b), offer and sell the remaining unsubscribed portion of such Offered New Securities to any Person at a price not less than, and upon terms no more favorable to the offeree than, those specified in the Offer Notice. If the Company does not enter into an agreement for the sale of the Offered New Securities within such period, or if such agreement is not consummated within thirty (30) days of the execution thereof, the right provided hereunder shall be deemed to be revived and such Offered New Securities shall not be offered unless first reoffered to the Holders in accordance with this Section 11.

 

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(d) A Holder shall be entitled to apportion the rights granted to it pursuant to this Section 11 among itself and its Affiliates, if any, in such proportions as it deems appropriate.

(e) Notwithstanding anything herein to the contrary, the rights set forth in this Section 11 shall not be applicable to (i) Shares, or rights or options with respect to Shares, issued to any officer, director, employee or consultant of the Company or any of its subsidiaries in accordance with Section 9, (ii) Shares, rights, convertible securities, options, or warrants issued by the Company as consideration for the acquisition of another Person or assets or properties of another Person, provided the aggregate consideration in the form of Shares, rights, convertible securities, options, or warrants for all such acquisitions shall not exceed $15,000,000, (iii) the Warrants, Shares of Preferred Stock issuable upon the exercise of Warrants or Shares of Common Stock issuable upon the conversion of Shares of Preferred Stock, (iv) the Convertible Notes or the Shares of Common Stock issuable upon conversion of the Convertible Notes, (v) Shares, rights, convertible securities, options, or warrants issuable upon the exercise or conversion of rights, convertible securities, options, or warrants issued after the date hereof (“Subsequently Issued Rights”), provided that the Company complied with its obligations under this Section 11 in connection with the issuance of such Subsequently Issued Rights (to the extent applicable), or (vi) Shares issued in a Qualified PO. For the avoidance of doubt, each Holder hereby waives compliance in all respects with Section 11 of the Original Agreement in connection with the offer and sale of the Convertible Notes.

12. Consent Rights. In addition to any approval rights of the shareholders of the Company set forth in the Company’s Certificate of Incorporation or the Bylaws and notwithstanding anything to the contrary in the Bylaws, so long as there are any Significant Holders, the Company shall not, without the consent of the Significant Holders holding a Significant Holder Majority:

(a) create, authorize, issue or obligate the Company to issue any class of Shares or other equity security of the Company or issue any option to purchase Shares or other equity security of the Company, other than (i) the issuance of Shares or options to purchase Shares to any officer, director, employee or consultant of the Company or any of its subsidiaries permitted under clause (b) of this Section 12 and (ii) the issuance of the Convertible Notes;

(b) issue Shares or options to purchase Shares to officers, directors, employees or consultants of the Company or any of its subsidiaries to the extent that the aggregate number of Shares and options to purchase Shares issued to such Persons after the date hereof would represent more than 15% of the Fully Diluted Outstanding Shares of the Company as of the date hereof;

(c) repurchase any of the Company’s equity securities;

(d) enter into any transaction of merger or consolidation, or liquidate, wind up or dissolve itself (or suffer any liquidation or dissolution), other than the merger of any subsidiary of the Company with and into Company with the Company as surviving entity;

 

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(e) sell, transfer, lease, license or dispose of all or substantially all of the Company’s assets or all or substantially all of the properties acquired pursuant to the Acquisition Agreement (as such term is defined in the Note Purchase Agreement);

(f) so long as (i) Significant Holders hold Warrants or Warrant Shares representing at least 20% of the Fully Diluted Outstanding Shares of the Company and (ii) Highbridge, Apollo and their respective Affiliates collectively purchase at least $50 million principal amount of Convertible Notes in the Convertible Notes Offering and continue to hold at least $50 million principal amount of Convertible Notes, except as otherwise set forth in the Company’s approved annual budget, make any capital expenditure or acquisition of any assets or interest or other investment in any Person (whether by purchase of assets, purchase of stock, merger or otherwise) for a purchase price of $75 million or more in aggregate per calendar year;

(g) so long as (i) Significant Holders hold Warrants or Warrant Shares representing at least 20% of the Fully Diluted Outstanding Shares of the Company and (ii) Highbridge, Apollo and their respective Affiliates collectively purchase at least $50 million principal amount of Convertible Notes in the Convertible Notes Offering and continue to hold at least $50 million principal amount of Convertible Notes, approve the Company’s budget or any overages of either the total capital expenditures or the total general and administrative expenses greater than ten percent (10%) for any 12 month period from the date of the approved budget (it being acknowledged that Significant Holders holding a Significant Holder Majority have consented to the Company’s budget through July 31, 2015);

(h) initiate any public offering of the Company or any subsidiary other than a Qualified PO;

(i) enter into or permit to exist any transaction (including the purchase, sale, lease or exchange of any property or the rendering of any service) with any Affiliate or Covered Person, or permit to exist any arrangement or understanding, regardless of whether such arrangement has been formalized, whereby services or the sale of any property are provided to an Affiliate or Covered Person on terms more favorable than that provided to the Company for similar services or any Affiliate or Covered Person provides the Company or any subsidiary of the Company with services related to the gathering and processing of hydrocarbons; provided, the foregoing restriction shall not apply to any transaction between the Company and its subsidiaries or any transaction between different subsidiaries of the Company;

(j) approve any voluntary bankruptcy, appointment of receivers or similar events involving the Company or any of its subsidiaries;

(k) fill any vacancy of chief executive officer or the chief financial officer of the Company because of death, resignation, removal, disqualification or other cause; or

 

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(l) amend, alter or change the Certificate of Incorporation or the Bylaws of the Company in a manner that adversely affects the economic interests of the Holders of Preferred Stock or the Warrantholders (assuming for purposes of this Section 12(l) that all Warrants was exercised as of the date hereof) ); provided, however, that consent of the Significant Holders pursuant to this Section 12 is hereby granted with respect to the amendment of the Certificate of Designations of the Series A Preferred Stock on the date hereof to conform the provisions of Section 4(b) of the Certificate of Designations of the Series A Preferred Stock to the provisions of this Section 12.

In furtherance of the foregoing, the Company and the Holders agree that the Company shall not take any action the sole intent of which is to circumvent the rights of the Significant Holders to approve the matters set forth above.

13. Subsequent Holders. All subsequent Holders of the Company shall be required to execute this Agreement, and all Shares and Warrants held by such subsequent Holders shall be subject to the terms hereof. The Company shall not issue any equity securities or rights, convertible securities, options, or warrants to purchase or otherwise acquire equity securities of the Company after the date hereof unless the Person to whom such equity securities, rights, convertible securities, options, or warrants are to be issued has executed this Agreement; provided that the foregoing shall not apply to the issuance of the Convertible Notes.

14. Modification and Waiver. The parties may amend, modify, supplement or terminate this Agreement, or waive compliance with or performance of any provision hereof, with the written consent of the Holders of at least seventy-five percent (75%) of the outstanding Shares of Common Stock on an As-Converted Basis in such manner as may be agreed upon by them in writing at any time; provided, however, that no such amendment that materially and adversely affects the rights of any Holder shall be binding on such Holder without such Holder’s written consent. The failure of any party at any time or times to require compliance with or performance of any provision hereof shall in no manner affect such party’s right at a later date to enforce the same. No waiver by any party of a breach of this Agreement, whether by conduct or otherwise, in any one or more instances shall be construed as a further or continuing waiver of such breach or a waiver of any condition or of any other breach of this Agreement. Notwithstanding the foregoing, no provision of Section 6 or Section 8 may amended, modified, supplemented or waived without the prior written consent of Highbridge and Pettit (to the extent that such Person’s rights under such Sections continue to be in effect).

15. Qualified PO. If the Board approves a Qualified PO, the Holders shall take all Necessary Actions reasonably requested by the Board in connection with the consummation of such Qualified PO, including, without limitation, (i) voting of all Shares held by the Stockholders in favor of approval of such Qualified PO (to the extent a vote of the stockholders of the Company is required or requested by the Board) and (ii) compliance with the requirements of all laws and regulatory bodies that are applicable or that have jurisdiction over such Qualified PO. If the managing underwriters in a Qualified PO advise the Company in writing that in their

 

-23-


opinion the Company’s capital structure would adversely affect the marketability of the offering, each Holder shall consent to and vote for a recapitalization, stock split, reorganization or exchange (each, a “Recapitalization”) of any class of the Company’s equity securities into another class of or number of securities of the Company or a successor that the managing underwriters and the Board find acceptable and shall take all Necessary Actions in connection with the consummation of such Recapitalization; provided that each Holder shall receive the same type and proportionate amount of any such securities and shall be subject to the same restrictions on lock-up and transferability unless otherwise agreed to by the Holders. Without limiting the foregoing, the Holders shall take all Necessary Actions in connection with a Qualified PO to increase the number of authorized Shares of Common Stock and Preferred Stock to an amount determined by the Company and the managing underwriters in a Qualified PO to be appropriate, including to provide sufficient authorized Shares of Common Stock to permit conversion of the Convertible Notes into Shares of Common Stock in accordance with the terms of the Convertible Notes. If requested by the managing underwriters in a Qualified PO, each Holder shall execute customary lock-up agreements with respect to their Shares and/or any securities received by them in any attendant Recapitalization.

16. Confidentiality. Each Holder agrees that, except as required by law or consented to in writing by the Company, it will, and will cause its directors, officers, employees, representatives and/or agents (collectively, “Representatives”) to, keep strictly confidential all information concerning the Company or its business, properties or plans; provided, however, that the foregoing shall not apply to (a) any Holder in such Holder’s capacity as an officer or director of the Company, (b) any information that is or becomes generally available to the public (other than as a result of a disclosure directly or indirectly by such Holder or its Representatives in violation hereof), (c) any disclosure of information to the investors, limited partners or potential investors of any Holder as such Holder may reasonably deem necessary or appropriate or (d) any information the disclosure of which is required by law, provided that the Holder promptly notifies the Company of, and takes reasonable steps to minimize the extent of, any such required disclosure.

17. Notices. Any and all notices, requests, consents or other communications permitted or required to be given under the terms of this Agreement shall be in writing and shall be deemed received (a) if given by facsimile transmission, when transmitted and the appropriate telephonic confirmation received if transmitted on a business day and during normal business hours of the recipient, and otherwise on the next business day following transmission, (b) if given by certified mail, return receipt requested, postage prepaid, three (3) business days after being deposited in the United States mails, and (c) if given by Federal Express service or other means, when received or personally delivered. The mailing address and facsimile number of each of the parties is as follows:

 

-24-


(a) If to the Company:    Energy & Exploration Partners, Inc.
   Attn: General Counsel
   Two City Place, Suite 1700
   100 Throckmorton
   Fort Worth, Texas 76102
   Facsimile: 817-533-9840

(b) If to the Holders, at the addresses and facsimile numbers reflected on Exhibit A attached hereto, or at such other address and/or facsimile number for any Holder as has been provided to the Company in writing by such Holder and is reflected in the Company’s books and records.

The address and facsimile number of any party may be changed by notice given in the manner provided in this Section 15.

18. Non-assignment. This Agreement shall not be assignable by any party without the written consent of all other parties hereto; provided, however, any Holder may assign its rights and obligations hereunder to any person to which it transfers any Shares or Warrants in compliance with this Agreement or the Warrants, except that rights of Highbridge and Pettit under Section 6 and Section 8 may not be assigned without the prior written consent of the Company. Subject to the foregoing, this Agreement shall be binding upon and inure to the benefit of the respective successors, assigns, heirs and personal representatives of the parties hereto.

19. Counterparts. This Agreement may be executed in any number of counterparts with the same effect as if the signatures to each counterpart were upon the same instrument.

20. Entire Agreement. This Agreement embodies the entire agreement and understanding of the parties with respect to the subject matter hereof, and supersedes all prior agreements or understandings (whether written or oral), with respect to the subject matter hereof. There are no restrictions, promises, representations, warranties, covenants or undertakings, other than those expressly set forth or referred to herein.

21. Headings. The headings in this Agreement are inserted for convenience and identification only and are not intended to describe, interpret, define, or limit the scope, extent, or intent of this Agreement or any provision hereof.

22. Governing Law. This Agreement shall be governed by and construed in accordance with the laws of the State of Delaware.

23. Severability. If any provisions contained in this Agreement shall for any reason be held invalid, illegal or unenforceable in any respect, such invalidity, illegality or unenforceability shall not invalidate the entire Agreement. Instead, such provision shall be deemed to be modified to the extent necessary to render it valid and enforceable and if no such modification shall render it valid and enforceable then the Agreement shall be construed as if not containing such provision.

 

-25-


24. Time of the Essence. Time is of the essence with respect to this Agreement.

25. No Third Party Beneficiaries. Nothing herein expressed or implied is intended to confer upon any person, other than the parties hereto or their respective permitted assigns, successors, heirs and legal representatives, any rights, remedies, obligations or liabilities under or by reason of this Agreement.

26. Termination of Agreement. Except as provided in next succeeding sentence, this Agreement shall terminate and be of no further force or effect upon the earlier of the consummation of a Qualified PO or the consummation of a Sale of the Company. Notwithstanding the foregoing, Section 8, Section 14, and Sections 17 through 26 of this Agreement shall survive the consummation of a Qualified PO and continue to be in full force and effect until such time as neither Highbridge nor Pettit shall be entitled to nominate Directors pursuant to Section 8 or the earlier Sale of the Company.

27. Effectiveness of Agreement. This Agreement is effective as of the Effective Date. Notwithstanding the foregoing or anything herein to the contrary, if the Convertible Notes Offering is not consummated under the Purchase Agreement for any reason by July 25, 2014 or the Convertible Notes Offering is terminated or abandoned prior to such date, then this Agreement shall be of no force or effect, and the Original Agreement shall continue in full force and effect as if this Agreement had not been entered into.

 

-26-


EXECUTED and delivered on the date first above written.

 

ENERGY & EXPLORATION PARTNERS, INC.
By:  

/s/ B. Hunt Pettit

Name: B. Hunt Pettit
Title:   President and Chief Executive Officer
H PETTIT HC, INC.
By:  

/s/ B. Hunt Pettit

Name: B. Hunt Pettit
Title:   President and Secretary

Signature Page to Second Amended and Restated Stockholders Agreement


Oso + Toro Multi Strategy Fund Series Interests of

the SALI Multi-Series Fund II 3(c)(1), L.P.

By:   SALI Fund Management, LLC
Its:   Investment Manager
By:  

/s/ Thomas A. Nieman

Name:   Thomas A. Nieman
Its:   Chief Financial Officer

Signature Page to Second Amended and Restated Stockholders Agreement


Oso + Toro Multi Strategy Fund (Tax Exempt) Segregated Portfolio of SALI Multi-Series Fund SPC, Ltd.
By:   SALI Fund Partners, LLC
Its:   General Partner
By:  

/s/ Thomas A. Nieman

Name:   Thomas A. Nieman
Its:   Chief Financial Officer

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Carl Lasner

Carl Lasner

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Jason Roberts

Jason Roberts

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Zachary Burk Lowe

Zachary Burk Lowe

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Janice Boswell Wueste

Janice Boswell Wueste

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Laura Pettit

Laura Pettit

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Matthew F. Ledbetter

Matthew F. Ledbetter

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Amber Boswell

Amber Boswell

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Brian Nelson

Brian Nelson

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ David Patty

David Patty

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Robert Karpman

Robert Karpman

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Tom McNutt

Tom McNutt

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Scott Burk

Scott Burk

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ John Richards

John Richards

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Chad Galloway

Chad Galloway

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Lawrence B. Van Ingen

Lawrence B. Van Ingen

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Steve Wilson

Steve Wilson

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Cody Smith

Cody Smith

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ John Foster Pettit, Jr.

John Foster Pettit, Jr.

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Elizabeth Pettit LaVaccare

Elizabeth Pettit LaVaccare

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Pamela Noelle Pennington

Pamela Noelle Pennington

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ TOM McNUTT

TOM McNUTT, as Trustee of the SYLVIA

SIGNOR FAMILY TRUST

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ TOM McNUTT

TOM McNUTT, as Trustee of the SYLVIA

SIGNOR EDUCATION TRUST

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ BRIAN HUNTLEY PETTIT

BRIAN HUNTLEY PETTIT, as Trustee of the

PETTIT 2012 CHILDREN’S TRUST

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ BRIAN HUNTLEY PETTIT

BRIAN HUNTLEY PETTIT, as Trustee of the

PETTIT 2012 FAMILY TRUST

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Jim Howe

Jim Howe

Signature Page to Second Amended and Restated Stockholders Agreement


/s/ Chase Hanna

Chase Hanna

Signature Page to Second Amended and Restated Stockholders Agreement


Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC
By:   Highbridge Principal Strategies Mezzanine Partners II GP, L.P.
Its:   Manager
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Don Dimitrievich

Name:   Don Dimitrievich
Title:   Managing Director

Signature Page to Second Amended and Restated Stockholders Agreement


Highbridge Principal Strategies – AP Mezzanine Partners II, L.P.
By:   Highbridge Principal Strategies Mezzanine Partners II GP, L.P.
Its:   General Partner
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Don Dimitrievich

Name:   Don Dimitrievich
Title:   Managing Director

Signature Page to Second Amended and Restated Stockholders Agreement


ENXP OFFSHORE, L.P.
By:   Highbridge Principal Strategies Mezzanine Partners II Offshore GP, L.P.
Its:   General Partner
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Don Dimitrievich

Name:   Don Dimitrievich
Title:   Managing Director

Signature Page to Second Amended and Restated Stockholders Agreement


ENXP INSTITUTIONAL, L.P.
By:   Highbridge Principal Strategies Mezzanine Partners II Offshore GP, L.P.
Its:   General Partner
By:   Highbridge Principal Strategies, LLC,
Its:   General Partner
By:  

/s/ Don Dimitrievich

Name:   Don Dimitrievich
Title:   Managing Director

Signature Page to Second Amended and Restated Stockholders Agreement


Apollo Investment Corporation
By:   Apollo Investment Management, L.P.
Its:   Advisor
By:   ACC Management, LLC
Its:   General Partner
By:  

/s/ Ted Goldthorpe

Name:   Ted Goldthorpe
Title:   President

Signature Page to Second Amended and Restated Stockholders Agreement


Apollo Special Opportunities Managed Account, L.P.
By:   Apollo SOMA Advisors, L.P., its general partner
By:   Apollo SOMA Capital Management, LLC, its general partner
By:  

/s/ Joseph D. Glatt

Name:   Joseph D. Glatt
Title:   Vice President and Assistant Secretary

Signature Page to Second Amended and Restated Stockholders Agreement


Apollo Centre Street Partnership, L.P.
By:   Apollo Centre Street Advisors (APO DC), L.P., its general partner
By:   Apollo Centre Street Advisors (APO DC-GP), LLC, its general partner
By:  

/s/ Joseph D. Glatt

Name:   Joseph D. Glatt
Title:   Vice President and Assistant Secretary

Signature Page to Second Amended and Restated Stockholders Agreement


ANS U.S. Holdings Ltd.
By:   Apollo SK Strategic Advisors, LLC, its sole director
By:  

/s/ Joseph D. Glatt

Name:   Joseph D. Glatt
Title:   Vice President and Assistant Secretary

Signature Page to Second Amended and Restated Stockholders Agreement


Exhibit A

HOLDERS

 

          Securities Owned

Holder

  

Address

   Shares of
Common
Stock
     Shares of
Series A
Preferred
Stock
   Shares of
Series B
Preferred
Stock
   Warrants to
Purchase
Series A
Preferred
Stock
   Warrants to
Purchase
Series B
Preferred
Stock

H PETTIT HC, Inc.

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      3               

Oso + Toro Multi Strategy Fund Series Interests of the SALI Multi-Series Fund II 3(c)(1), L.P.

   6836 Austin Center Boulevard, Suite 320, Austin, Texas 78731      56,604               

Oso + Toro Multi Strategy Fund (Tax Exempt) Segregated Portfolio of SALI Multi-Series Fund SPC, Ltd.

   6836 Austin Center Boulevard, Suite 320, Austin, Texas 78731      37,736               

Carl Lasner

   1225 Red Hawk Road, Wimberley, TX 78676      943               

Jason Roberts

   3005 Amherst Avenue, Dallas, TX 75225      5,050               

Zachary Burk Lowe

   4154 Santa Barbara Drive, Dallas, TX 75214      2,358               

Janice Boswell Wueste

   2845 Manorwood Trail, Fort Worth, TX 76109      717               

Laura Pettit

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      360               

Matthew F. Ledbetter

   5309 Judalon Lane, Houston, TX 77056      897               

Amber Boswell

   2721 Manorwood Trail, Fort Worth, TX 76109      8,804               

Brian Nelson

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      50,000               

David Patty

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      25,000               

Robert Karpman

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      15,000               

Tom McNutt

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      10,000               

 

A-1


          Securities Owned

Holder

  

Address

   Shares of
Common
Stock
     Shares of
Series A
Preferred
Stock
   Shares of
Series B
Preferred
Stock
   Warrants to
Purchase
Series A
Preferred
Stock
   Warrants to
Purchase
Series B
Preferred
Stock

Scott Burk

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

Chad Galloway

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      5,000               

Lawrence B. Van Ingen

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

Steve Wilson

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

Cody Smith

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      2,500               

John Foster Pettit, Jr.

  

P. O. Box 1564

Uvalde, TX 78802

physical:

3102 Eisenhauer #A9

San Antonio, TX 78209

     1,169               

Elizabeth Pettit LaVaccare

  

5540 Millwick Dr.

Alpharetta, GA 30005-2572

     1,169               

Pamela Noelle Pennington

  

1940 Hawthorne Loop

Driftwood, Texas 78619

     1,169               

Sylvia Signor Family Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      4,678               

Sylvia Signor Education Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      9,356               

Pettit 2012 Children’s Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      43,588               

Pettit 2012 Family Trust

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      197,899               

John Richards

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      12,821               

 

A-2


          Securities Owned  

Holder

  

Address

   Shares of
Common
Stock
     Shares of
Series A
Preferred
Stock
   Shares of
Series B
Preferred
Stock
   Warrants to
Purchase
Series A
Preferred
Stock
    Warrants to
Purchase
Series B
Preferred
Stock
 

Jim Howe

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      5,130              

Chase Hanna

   Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102      5,079              

Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              39,018 1      35,630 1 

Highbridge Principal Strategies – AP Mezzanine Partners II, L.P.

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              4,549        4,118   

ENXP Offshore, L.P.

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              63,955        58,396   

ENXP Institutional, L.P.

  

40 West 57th Street, 33rd Floor

New York, NY 10019

              6,864        6,268   

Apollo Investment Corporation

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              60,778     

Apollo Special Opportunities Managed Account, L.P.

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              35,251     

Apollo Centre Street Partnership, L.P.

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              18,233     

ANS U.S. Holdings Ltd.

  

c/o Apollo Management, L.P.

9 W 57TH Street

New York, NY 10019

Attn: Joseph Glatt

              7,293     

 

1  These warrants issued to Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC on April 8, 2013 and March 27, 2014 have been pledged pursuant to that certain Credit Agreement, dated as of December 20, 2012 to which Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC is a party.

 

A-3


Exhibit B

BOARD OF DIRECTORS AT DATE OF AGREEMENT

At the date of this Agreement, the number of Directors constituting the full Board shall be seven, and the Directors shall be the following individuals:

B. Hunt Pettit

Brian Nelson

Tom McNutt

David Patty

Laurie Van Ingen

John T. Richards

Don Dimitrievich

 

B-1



Exhibit 4.7

AMENDMENT TO WARRANT TO

PURCHASE SERIES A PREFERRED STOCK

OF

ENERGY & EXPLORATION PARTNERS, INC.

THIS AMENDMENT TO WARRANT TO PURCHASE SERIES A PREFERRED STOCK (this “Amendment”), is entered into by and between Energy & Exploration Partners, Inc. (the “Company”) and [            ] (“Holder”), as of July 10, 2014 (the “Effective Date”).

R E C I T A L S

WHEREAS, the Company and Holder have entered into that certain Warrant to Purchase Series A Preferred Stock dated [            ] (the “Warrant”);

WHEREAS, the parties hereto desire to make certain amendments to the Warrant as provided herein;

WHEREAS, capitalized terms not otherwise defined herein shall have the meaning given them in, or incorporated by reference in, the Warrant.

NOW, THEREFORE, in consideration of the mutual premises set forth herein, the Company and Holder agree and consent to amend the Warrant as follows:

ARTICLE I

AMENDMENTS TO WARRANT

Section 1.1. Amendments to Section 1.

(a) Section 1 of the Warrant is hereby amended by amending and restating the following definitions their entirety:

Note Purchase Agreement” means the Note Purchase Agreement, dated as of April 8, 2013, by and among Energy & Exploration Partners, Inc., as Issuer, Cortland Capital Market Services LLC, as administrative agent for the Holders, and the Holders named therein, as amended, supplemented or otherwise modified prior to the date hereof.

Qualified Public Offering” means the first public offering of the Common Stock (a) in which the aggregate gross proceeds to the Company and the stockholders selling such Common Stock, if any, equal or exceed $400.0 million and (b) following which, such Common Stock is listed on a U.S. national securities exchange. For the avoidance of doubt, if a Qualified Public Offering does not successfully close, it shall not prevent a future public offering from qualifying and being treated as a “Qualified Public Offering”.

Registration Rights Agreement” means the Second Amended and Restated Registration Rights Agreement dated as of July 10, 2014, among the Company and the other parties thereto, and as the same shall be amended from time to time.


Stockholders Agreement” means that certain Second Amended and Restated Stockholders Agreement dated as of July 10, 2014, by and among the Company, all of the owners of the capital stock of the Company and all holders of Warrants and Series B Warrants.

(a) Section 1 of the Warrant is hereby amended by inserting the following definitions in the alphabetically appropriate order:

First Amendment to Warrant” means that certain Amendment to Warrant to Purchase Series A Preferred Stock, dated as of July 10, 2014, among the Company and the Holder.

Section 1.2 General Amendment. The phrase “Qualified Public Offering” shall replace the phrase “Qualified Initial Public Offering” in each instance in the Warrant where such phrase appears.

ARTICLE II

MISCELLANEOUS

Section 2.1 Warrant Ratification. Except as amended hereby, the Warrant shall remain in full force and effect, and the parties hereto hereby ratify the Warrant as amended hereby.

Section 2.2 Counterparts. This Amendment may be executed in any number of counterparts, each of which when so executed and delivered shall be deemed an original, but all such counterparts together shall constitute but one and the same instrument.

Section 2.3 Complete Agreement. This Amendment, the Note Purchase Agreement and the other Note Documents represent the final agreement among the parties and may not be contradicted by evidence of prior, contemporaneous, or subsequent oral agreements of the parties. There are no unwritten oral agreements among the parties.

Section 2.4 Governing Law. ALL ISSUES AND QUESTIONS CONCERNING THE APPLICATION, CONSTRUCTION, VALIDITY, INTERPRETATION AND ENFORCEMENT OF THIS AMENDMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF DELAWARE, WITHOUT GIVING EFFECT TO ANY CHOICE OF LAW OR CONFLICT OF LAW PROVISION OR RULE (WHETHER OF THE STATE OF DELAWARE OR ANY OTHER JURISDICTION) THAT WOULD CAUSE THE APPLICATION OF THE LAWS OF ANY JURISDICTION OTHER THAN THE STATE OF DELAWARE.

Section 2.5 Effectiveness. This Amendment is effective as of the Effective Date. Notwithstanding the foregoing or anything herein to the contrary, if the Convertible Notes Offering (as defined in the Stockholders Agreement) is not consummated under that certain Purchase Agreement, dated July 10, 2014, between the Company and Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC/Seaport Group Securities, LLC, as representatives of the initial purchasers named therein, with respect to the


Convertible Notes for any reason by July 25, 2014 or the Convertible Notes Offering is terminated or abandoned prior to such date, then this Amendment shall be of no force or effect, and the Warrant shall continue in full force and effect as if this Amendment had not been entered into.


IN WITNESS WHEREOF, the undersigned have duly executed this Amendment as of the date first above written.

 

COMPANY:
ENERGY & EXPLORATION PARTNERS, INC.
By:  

 

Name:  
Title:  
HOLDER:
[            ]
By:  

 

Name:  
Title:  


Exhibit 4.8

AMENDMENT TO WARRANT TO

PURCHASE SERIES B PREFERRED STOCK

OF

ENERGY & EXPLORATION PARTNERS, INC.

THIS AMENDMENT TO WARRANT TO PURCHASE SERIES B PREFERRED STOCK (this “Amendment”), is entered into by and between Energy & Exploration Partners, Inc. (the “Company”) and [            ] (“Holder”), as of July 10, 2014 (the “Effective Date”).

R E C I T A L S

WHEREAS, the Company and Holder have entered into that certain Warrant to Purchase Series B Preferred Stock dated [            ] (the “Warrant”);

WHEREAS, the parties hereto desire to make certain amendments to the Warrant as provided herein;

WHEREAS, capitalized terms not otherwise defined herein shall have the meaning given them in, or incorporated by reference in, the Warrant.

NOW, THEREFORE, in consideration of the mutual premises set forth herein, the Company and Holder agree and consent to amend the Warrant as follows:

ARTICLE I

AMENDMENTS TO WARRANT

Section 1.1. Amendments to Section 1.

(a) Section 1 of the Warrant is hereby amended by amending and restating the following definitions their entirety:

Note Purchase Agreement” means the Note Purchase Agreement, dated as of April 8, 2013, by and among Energy & Exploration Partners, Inc., as Issuer, Cortland Capital Market Services LLC, as administrative agent for the Holders, and the Holders named therein, as amended, supplemented or otherwise modified prior to the date hereof.

Qualified Public Offering” means the first public offering of the Common Stock (a) in which the aggregate gross proceeds to the Company and the stockholders selling such Common Stock, if any, equal or exceed $400.0 million and (b) following which, such Common Stock is listed on a U.S. national securities exchange. For the avoidance of doubt, if a Qualified Public Offering does not successfully close, it shall not prevent a future public offering from qualifying and being treated as a “Qualified Public Offering”.

Registration Rights Agreement” means the Second Amended and Restated Registration Rights Agreement dated as of July 10, 2014, among the Company and the other parties thereto, and as the same shall be amended from time to time.


Stockholders Agreement” means that certain Second Amended and Restated Stockholders Agreement dated as of July 10, 2014, by and among the Company, all of the owners of the capital stock of the Company and all holders of Warrants and Series A Warrants.

(a) Section 1 of the Warrant is hereby amended by inserting the following definitions in the alphabetically appropriate order:

First Amendment to Warrant” means that certain Amendment to Warrant to Purchase Series B Preferred Stock, dated as of July 10, 2014, among the Company and the Holder.

Section 1.2 General Amendment. The phrase “Qualified Public Offering” shall replace the phrase “Qualified Initial Public Offering” in each instance in the Warrant where such phrase appears.

ARTICLE II

MISCELLANEOUS

Section 2.1 Warrant Ratification. Except as amended hereby, the Warrant shall remain in full force and effect, and the parties hereto hereby ratify the Warrant as amended hereby.

Section 2.2 Counterparts. This Amendment may be executed in any number of counterparts, each of which when so executed and delivered shall be deemed an original, but all such counterparts together shall constitute but one and the same instrument.

Section 2.3 Complete Agreement. This Amendment, the Note Purchase Agreement and the other Note Documents represent the final agreement among the parties and may not be contradicted by evidence of prior, contemporaneous, or subsequent oral agreements of the parties. There are no unwritten oral agreements among the parties.

Section 2.4 Governing Law. ALL ISSUES AND QUESTIONS CONCERNING THE APPLICATION, CONSTRUCTION, VALIDITY, INTERPRETATION AND ENFORCEMENT OF THIS AMENDMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF DELAWARE, WITHOUT GIVING EFFECT TO ANY CHOICE OF LAW OR CONFLICT OF LAW PROVISION OR RULE (WHETHER OF THE STATE OF DELAWARE OR ANY OTHER JURISDICTION) THAT WOULD CAUSE THE APPLICATION OF THE LAWS OF ANY JURISDICTION OTHER THAN THE STATE OF DELAWARE.

Section 2.5 Effectiveness. This Amendment is effective as of the Effective Date. Notwithstanding the foregoing or anything herein to the contrary, if the Convertible Notes Offering (as defined in the Stockholders Agreement) is not consummated under that certain Purchase Agreement, dated July 10, 2014, between the Company and Citigroup Global Markets Inc., Credit Suisse Securities (USA) LLC and Global Hunter Securities, LLC/Seaport Group Securities, LLC, as representatives of the initial purchasers named therein, with respect to the Convertible Notes for any reason by July 25, 2014 or the Convertible Notes Offering is


terminated or abandoned prior to such date, then this Amendment shall be of no force or effect, and the Warrant shall continue in full force and effect as if this Amendment had not been entered into.


IN WITNESS WHEREOF, the undersigned have duly executed this Amendment as of the date first above written.

 

COMPANY:
ENERGY & EXPLORATION PARTNERS, INC.
By:  

 

Name:  
Title:  
HOLDER:
[            ]
By:  

 

Name:  
Title:  


Exhibit 4.9

SECOND AMENDMENT TO WARRANT TO

PURCHASE SERIES B PREFERRED STOCK

OF

ENERGY & EXPLORATION PARTNERS, INC.

THIS SECOND AMENDMENT TO WARRANT TO PURCHASE SERIES B PREFERRED STOCK (this “Amendment”), is entered into by and between Energy & Exploration Partners, Inc. (the “Company”) and [            ] (“Holder”), as of July 31, 2014 (the “Effective Date”).

R E C I T A L S

WHEREAS, the Company and Holder have entered into that certain Warrant to Purchase Series B Preferred Stock dated [            ], as amended on July 10, 2014 (the “Warrant”);

WHEREAS, the parties hereto desire to make certain amendments to the Warrant as provided herein;

WHEREAS, capitalized terms not otherwise defined herein shall have the meaning given them in, or incorporated by reference in, the Warrant.

NOW, THEREFORE, in consideration of the mutual premises set forth herein, the Company and Holder agree and consent to amend the Warrant as follows:

ARTICLE I

AMENDMENTS TO WARRANT

Section 1.1. Amendments to Section 1.

(a) Section 1 of the Warrant is hereby amended by deleting the following definitions:

Convertible Notes” means $375 million principal amount of the Company’s 8.0% Convertible Subordinated Notes due 2019 to be issued on or about July 22, 2014 pursuant to an Indenture to be dated as of July 22, 2014 between the Company and U.S. Bank National Association, as trustee.

Convertible Note Shares” means the Shares of Common Stock received upon the conversion of the Convertible Notes.

FIRPTA Certificate” has the meaning set forth in Section 9.3(a).

First Amendment to Warrant” means that certain Amendment to Warrant to Purchase Series B Preferred Stock, dated as of July 10, 2014, among the Company and the Holder.

Per Share Cash Amount” has the meaning set forth in Section 2.1(d).


Reduced Shares” means a number of Shares of Common Stock that would otherwise be issuable to the Holder in the deemed exercise of this Warrant upon the consummation of a Qualified Public Offering pursuant to Section 2.1(d) equal to the greater of (i) the number of such Shares determined in good faith by the tax advisor to the Holder to ensure that the Holder would not be a “10-percent shareholder” of the Company as determined under Sections 871(h)(3) and 881(c) of the Code and Treasury Regulations Section 1.871-14(g) as a result of or following such exercise, taking into account any other Shares treated as owned, directly or indirectly, by the Holder pursuant to Treasury Regulations Section 1.871-14(g)(2)(ii) including upon the exercise of any other security, warrant or option owned by the Holder in respect of Shares of the Company that is convertible in a Qualified Public Offering, and (ii) a number of Shares the aggregate Per Share Cash Amount of which, when aggregated with any cash proceeds to be received by the Holder from the sale of Convertible Note Shares in a Qualified Public Offering, is equal to the maximum amount of the potential withholding obligation of the Company pursuant to Section 1445 in respect of the deemed exercise of this Warrant for Shares of Common Stock and cash pursuant to Section 2.1(d); provided, however, that if the number of Reduced Shares would otherwise not be a whole number, it shall be rounded up to the next whole number.

Section 1.2. Amendment to Section 2. Section 2.1(d) is hereby amended and restated in its entirety as follows:

(d) Conversion Upon Qualified Public Offering. Upon the consummation of a Qualified Public Offering of the Company, the Holder shall be deemed to have exercised this Warrant in full, without payment of the Exercise Price therefor, for a number of Shares of Common Stock equal to (i) the number of Shares of Common Stock into which the Shares of Series B Preferred Stock issuable upon exercise of this Warrant would have been converted upon consummation of the Qualified Public Offering if such Shares of Series B Preferred Stock had been outstanding immediately prior to the consummation of the Qualified Public Offering minus (ii) a number of Shares of Common Stock determined by dividing (A) the aggregate Exercise Price for the Shares of Series B Preferred Stock issuable upon exercise of this Warrant immediately prior to the consummation of the Qualified Public Offering by (B) the public offering price per Share of Common Stock in the Qualified Public Offering. As promptly as practicable after the consummation of the Qualified Public Offering, and in any event within three (3) Business Days thereafter, the Company shall execute or cause to be executed and deliver or cause to be delivered to Holder a certificate reflecting Holder’s ownership of the aggregate number of Shares of Common Stock issuable upon such deemed exercise of this Warrant, together with cash in lieu of any fraction of a Share of Common Stock, as hereinafter provided in Section 2.3. The Company shall update its records to reflect ownership of such Shares of Common Stock in the name of Holder. Such Shares of Common Stock shall be deemed to have been issued, and Holder shall be deemed to have become a holder of record of such Shares of Common Stock for all purposes, as of the date of the consummation of the Qualified Public Offering.


Section 1.3 Amendment to Section 9. Section 9.3 is hereby amended and restated in its entirety as follows:

9.3 Withholding. If the Company determines that U.S. federal withholding of Tax with respect to the Warrants or the Warrant Shares held by any Holder is necessary, the Company shall use commercially reasonable efforts to notify such Holder reasonably in advance of such withholding, and provide such Holder with a reasonable opportunity to establish an exemption or other basis for reducing or eliminating such U.S. federal withholding Tax. The Company shall cooperate with each Holder, and shall use commercially reasonable efforts to provide each Holder with information that any such Holder may request, in connection with such Holder’s Tax reporting and U.S. federal withholding Tax obligations relating to the Warrants and the Warrant Shares, including, with respect to each distribution payable on the Warrant Shares (whether in cash or in kind) or deemed distributed on the Warrant or Warrant Shares, providing such Holder with a contemporaneous reasonable estimate as to the amount of any such dividend that is expected to be treated as a dividend pursuant to section 301(c)(1) of the Code.

ARTICLE II

MISCELLANEOUS

Section 2.1 Warrant Ratification. Except as amended hereby, the Warrant shall remain in full force and effect, and the parties hereto hereby ratify the Warrant as amended hereby.

Section 2.2 Counterparts. This Amendment may be executed in any number of counterparts, each of which when so executed and delivered shall be deemed an original, but all such counterparts together shall constitute but one and the same instrument.

Section 2.3 Complete Agreement. This Amendment represents the final agreement among the parties and may not be contradicted by evidence of prior, contemporaneous, or subsequent oral agreements of the parties. There are no unwritten oral agreements among the parties.

Section 2.4 Governing Law. ALL ISSUES AND QUESTIONS CONCERNING THE APPLICATION, CONSTRUCTION, VALIDITY, INTERPRETATION AND ENFORCEMENT OF THIS AMENDMENT SHALL BE GOVERNED BY AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF DELAWARE, WITHOUT GIVING EFFECT TO ANY CHOICE OF LAW OR CONFLICT OF LAW PROVISION OR RULE (WHETHER OF THE STATE OF DELAWARE OR ANY OTHER JURISDICTION) THAT WOULD CAUSE THE APPLICATION OF THE LAWS OF ANY JURISDICTION OTHER THAN THE STATE OF DELAWARE.


IN WITNESS WHEREOF, the undersigned have duly executed this Amendment as of the date first above written.

 

COMPANY:
ENERGY & EXPLORATION PARTNERS, INC.
By:  

 

Name:
Title:
HOLDER:
[            ]
By:  

 

Name:
Title:


Exhibit 10.1

EXECUTION VERSION

 

 

 

CREDIT AGREEMENT

dated as of

July 22, 2014

among

ENERGY & EXPLORATION PARTNERS, INC.,

as Holdings,

ENERGY & EXPLORATION PARTNERS, LLC,

as Borrower,

THE LENDERS PARTY HERETO

and

CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH,

as Administrative Agent and Collateral Agent

 

 

CITIGROUP GLOBAL MARKETS INC.,

CREDIT SUISSE SECURITIES (USA) LLC

and

GLOBAL HUNTER SECURITIES, LLC/SEA PORT GROUP SECURITIES, LLC,

as Joint Bookrunners and Joint Lead Arrangers

 

 

 


TABLE OF CONTENTS

 

          Page  

Article I.

   Definitions      1   

Section 1.01

  

Defined Terms

     1   

Section 1.02

  

Terms Generally

     35   

Section 1.03

  

Pro Forma Calculations

     36   

Section 1.04

  

Classification of Loans and Borrowings

     36   

Article II.

   The Credits      36   

Section 2.01

  

Commitments

     36   

Section 2.02

  

Loans

     36   

Section 2.03

  

Borrowing Procedure

     37   

Section 2.04

  

Evidence of Debt; Repayment of Loans

     38   

Section 2.05

  

Fees

     38   

Section 2.06

  

Interest on Loans

     39   

Section 2.07

  

Default Interest

     39   

Section 2.08

  

Alternate Rate of Interest

     39   

Section 2.09

  

Termination of Commitments

     39   

Section 2.10

  

Conversion and Continuation of Borrowings

     40   

Section 2.11

  

Repayment of Loans

     41   

Section 2.12

  

Voluntary Prepayment

     42   

Section 2.13

   Mandatory Prepayments      43   


Table of Contents

 

          Page  

Section 2.14

  

Reserve Requirements; Change in Circumstances

     44   

Section 2.15

  

Change in Legality

     45   

Section 2.16

  

Breakage

     46   

Section 2.17

  

Pro Rata Treatment

     46   

Section 2.18

  

Sharing of Setoffs

     46   

Section 2.19

  

Payments

     47   

Section 2.20

  

Taxes

     47   

Section 2.21

  

Assignment of Commitments Under Certain Circumstances; Duty to Mitigate

     52   

Section 2.22

  

Defaulting Lenders

     53   

Section 2.23

  

Incremental Commitments

     54   

Article III.

  

Representations and Warranties

     55   

Section 3.01

  

Organization; Powers

     55   

Section 3.02

  

Authorization

     56   

Section 3.03

  

Enforceability

     56   

Section 3.04

  

Governmental Approvals

     56   

Section 3.05

  

Financial Statements

     56   

Section 3.06

  

No Material Adverse Change

     57   

Section 3.07

  

Title to Properties; Possession Under Leases

     57   

Section 3.08

  

Subsidiaries

     58   


Table of Contents

 

          Page  

Section 3.09

  

Litigation; Compliance with Laws

     58   

Section 3.10

  

Agreements

     59   

Section 3.11

  

Federal Reserve Regulations

     59   

Section 3.12

  

Investment Company Act

     59   

Section 3.13

  

Use of Proceeds

     59   

Section 3.14

  

Tax Returns

     59   

Section 3.15

  

No Material Misstatements

     59   

Section 3.16

  

Employee Benefit Plans

     60   

Section 3.17

  

Environmental Matters

     60   

Section 3.18

  

Insurance

     61   

Section 3.19

  

Security Documents

     61   

Section 3.20

  

Location of Business and Offices

     61   

Section 3.21

  

Labor Matters

     61   

Section 3.22

  

Solvency

     62   

Section 3.23

  

Sanctioned Persons; Patriot Act; FCPA

     62   

Section 3.24

  

Marketing of Production

     63   

Section 3.25

  

Hedging Agreements

     63   

Section 3.26

  

Gas Balancing Agreements and Advance Payment Contracts

     63   

Section 3.27

  

Absence of Defaults

     63   


Table of Contents

 

          Page  

Article IV.

  

Conditions of Lending

     64   

Section 4.01

  

Closing Date

     64   

Article V.

  

Affirmative Covenants

     67   

Section 5.01

  

Existence; Compliance with Laws; Businesses

     67   

Section 5.02

  

Operation and Maintenance of Properties

     67   

Section 5.03

  

Insurance

     68   

Section 5.04

  

Obligations and Taxes

     68   

Section 5.05

  

Financial Statements, Reports, etc

     69   

Section 5.06

  

Litigation and Other Notices

     71   

Section 5.07

  

Information Regarding Collateral

     71   

Section 5.08

  

Maintaining Records; Access to Properties and Inspections

     71   

Section 5.09

  

Use of Proceeds

     72   

Section 5.10

  

Employee Benefits

     72   

Section 5.11

  

[Reserved]

     72   

Section 5.12

  

Environmental Matters

     72   

Section 5.13

  

Further Assurances

     73   

Section 5.14

  

Additional Collateral; Additional Guarantors

     73   

Section 5.15

  

Reserve Reports

     74   

Section 5.16

  

Title Information

     75   


Table of Contents

 

          Page  

Section 5.17

  

Hedging Agreements

     76   

Article VI.

  

Negative Covenants

     76   

Section 6.01

  

Indebtedness

     76   

Section 6.02

  

Liens

     78   

Section 6.03

  

Sale and Lease-Back Transactions

     79   

Section 6.04

  

Investments, Loans and Advances

     79   

Section 6.05

  

Mergers, Consolidations, Dispositions and Acquisitions

     80   

Section 6.06

  

Restricted Payments

     82   

Section 6.07

  

Restrictive Agreements

     84   

Section 6.08

  

Transactions with Affiliates

     85   

Section 6.09

  

Business of Borrower and Subsidiaries; International Operations

     85   

Section 6.10

  

Certain Amendments and Modifications; Other Indebtedness

     86   

Section 6.11

  

[Reserved]

     86   

Section 6.12

  

Maximum Leverage Ratio

     86   

Section 6.13

  

[Reserved]

     87   

Section 6.14

  

Fiscal Year

     87   

Section 6.15

  

Hedging Agreements

     87   

Section 6.16

  

Certain Equity Securities

     87   

Section 6.17

  

Limitation on Leases

     87   


Table of Contents

 

          Page  

Section 6.18

  

Sale or Discount of Receivables

     87   

Section 6.19

  

Gas Balancing Agreements and Advance Payment Contracts

     87   

Section 6.20

  

Marketing Activities

     88   

Section 6.21

  

Holdings Covenants

     88   

Article VII.

  

Events of Default

     89   

Section 7.01

  

Events of Default

     89   

Section 7.02

  

Borrower’s Right to Cure

     92   

Article VIII.

  

The Administrative Agent and the Collateral Agent; Etc.

     93   

Section 8.01

  

Appointment and Authority

     93   

Section 8.02

  

Rights as a Lender

     93   

Section 8.03

  

Exculpatory Provisions

     93   

Section 8.04

  

Reliance by Agent

     94   

Section 8.05

  

Delegation of Duties

     94   

Section 8.06

  

Resignation of Agent

     94   

Section 8.07

  

Non-Reliance on Agent and Other Lenders

     95   

Section 8.08

  

No Other Duties

     95   

Section 8.09

  

Collateral and Guaranty Matters

     95   

Article IX.

  

Miscellaneous

     96   

Section 9.01

  

Notices; Electronic Communications

     96   


Table of Contents

 

          Page  

Section 9.02

  

Survival of Agreement

     98   

Section 9.03

  

Binding Effect

     99   

Section 9.04

  

Successors and Assigns

     99   

Section 9.05

  

Expenses; Indemnity

     106   

Section 9.06

  

Right of Setoff

     108   

Section 9.07

  

Applicable Law

     108   

Section 9.08

  

Waivers; Amendment

     108   

Section 9.09

  

Interest Rate Limitation

     110   

Section 9.10

  

Entire Agreement

     110   

Section 9.11

  

WAIVER OF JURY TRIAL

     110   

Section 9.12

  

Severability

     110   

Section 9.13

  

Counterparts

     111   

Section 9.14

  

Headings

     111   

Section 9.15

  

Jurisdiction; Consent to Service of Process

     111   

Section 9.16

  

Confidentiality

     111   

Section 9.17

  

Lender Action

     112   

Section 9.18

  

USA PATRIOT Act Notice

     112   

Section 9.19

  

[Reserved]

     113   

Section 9.20

  

Secured Hedging Agreements

     113   


Table of Contents

 

              Page
SCHEDULES              

Schedule 1.01(a)

  -   

Subsidiary Guarantors

  

Schedule 1.01(b)

  -   

Material Contracts

  

Schedule 2.01

  -   

Lenders and Commitments

  

Schedule 3.08

  -   

Subsidiaries

  

Schedule 3.09

  -   

Litigation

  

Schedule 3.14

  -   

Payment of Taxes

  

Schedule 3.17

  -   

Environmental Matters

  

Schedule 3.18

  -   

Insurance

  

Schedule 3.19(a)

  -   

Filing Offices

  

Schedule 3.19(b)

  -   

Mortgage Filing Offices

  

Schedule 3.24

  -   

Marketing Contracts

  

Schedule 3.25

  -   

Hedging Agreements

  

Schedule 3.26

  -   

Gas Balancing Agreements

  

Schedule 6.01

  -   

Existing Indebtedness

  

Schedule 6.02

  -   

Existing Liens

  

Schedule 6.07

  -   

Restrictive Agreements

  

Schedule 6.08

  -   

Transactions with Affiliates

  

EXHIBITS

 

Exhibit A-1

  -   

Form of Assignment and Acceptance

  

Exhibit A-2

  -   

Form of Borrower Purchase Assignment and Acceptance

  

Exhibit A-3

  -   

Form of Affiliated Lender Assignment and Acceptance

  

Exhibit B

  -   

Form of Borrowing Request

  

Exhibit C

  -   

[Reserved]

  

Exhibit D

  -   

Form of Compliance Certificate

  

Exhibit E

  -   

[Reserved]

  

Exhibit F

  -   

[Reserved]

  

Exhibit G-1

  -   

Form of U.S. Tax Compliance Certificate

  

Exhibit G-2

  -   

Form of U.S. Tax Compliance Certificate

  

Exhibit G-3

  -   

Form of U.S. Tax Compliance Certificate

  

Exhibit G-4

  -   

Form of U.S. Tax Compliance Certificate

  

Exhibit H

  -   

Form of Mortgage

  


CREDIT AGREEMENT dated as of July 22, 2014 (as amended, restated, supplemented or otherwise modified from time to time, this “Agreement”), among ENERGY & EXPLORATION PARTNERS, INC., a Delaware corporation (“Holdings”), ENERGY & EXPLORATION PARTNERS, LLC, a Delaware limited liability company (the “Borrower”), the Lenders (such term and each other capitalized term used but not defined in this preamble and the introductory statement below having the meaning given it in Article I), and CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH, acting through one or more of its branches or affiliates (“Credit Suisse”), as administrative agent (in such capacity, including any successor thereto, the “Administrative Agent”) and as collateral agent (in such capacity, including any successor thereto, the “Collateral Agent”) for the Lenders.

RECITALS

A. The Borrower has requested that the Lenders extend credit in the form of Loans on the Closing Date in an aggregate principal amount equal to $775,000,000. The proceeds of the Loans are to be used, together with the proceeds of the Holdings Notes, solely (i) to purchase exploration and production assets from Treadstone Energy Partners, LLC pursuant to the Acquisition Agreement (the “Acquisition”), (ii) to refinance and replace all amounts outstanding under (x) Holdings’ Senior Tranche A Notes, Tranche B Notes and Tranche C Notes due 2018 and Senior Tranche D Notes due 2019 and (y) the Borrower’s Senior Secured Tranche A Notes due 2016 (the existing Indebtedness referred to in clauses (x) and (y), collectively, the “Existing Debt”), (iii) to fund drilling capital expenditures and other working capital needs and general corporate purposes (including Permitted Acquisitions) and (iv) to pay fees and expenses in connection with the foregoing transactions (the “Transaction Costs”).

B. The Borrower desires to secure, among other specified obligations, all of the Obligations under the Loan Documents by granting to the Collateral Agent, for the benefit of the Secured Parties, a security interest in and Lien on substantially all of the property and assets of the Loan Parties, subject to the limitations described herein and in the Security Documents.

C. The Lenders are willing to extend such credit to the Borrower, on the terms and subject to the conditions set forth herein. Accordingly, the parties hereto agree as follows:

1.

Definitions

A. Defined Terms. As used in this Agreement, the following terms shall have the meanings specified below:

$” or “Dollars” shall mean lawful money of the United States of America.

ABR”, when used in reference to any Loan or Borrowing, refers to whether such Loan, or the Loans comprising such Borrowing, are bearing interest at a rate determined by reference to the Alternate Base Rate.

Acquisition” shall have the meaning assigned to such term in the recitals hereto.


Acquisition Agreement” shall mean the Purchase and Sale Agreement dated as of June 13, 2014, among Energy & Exploration Partners, LLC and Treadstone Energy Partners, LLC.

Adjusted LIBO Rate” shall mean, with respect to any Eurodollar Borrowing for any Interest Period, an interest rate per annum equal to the greater of (a) 1.00% per annum and (b) the product of (i) the LIBO Rate in effect for such Interest Period and (ii) Statutory Reserves.

Administrative Agent” shall have the meaning assigned to such term in the preamble to this Agreement.

Administrative Agent Fees” shall have the meaning assigned to such term in Section 2.05(a).

Administrative Questionnaire” shall mean an Administrative Questionnaire in such form as may be supplied from time to time by the Administrative Agent.

Affiliate” shall mean, when used with respect to a specified Person, another Person that directly, or indirectly through one or more intermediaries, Controls or is Controlled by or is under common Control with the Person specified; provided, however, that, for purposes of the Section 6.08 and the definition of “Affiliated Lender”, the term “Affiliate” shall also include any Person that directly or indirectly owns 10% or more of any class of Equity Interests of the Person specified or that is an officer or director of the Person specified.

Affiliated Lender” shall mean, at any time, any Lender that is an Affiliate of Holdings or the Borrower at such time (other than Holdings and the Borrower and its Subsidiaries).

Affiliated Lender Assignment and Acceptance” shall mean an Affiliated Lender Assignment and Acceptance substantially in the form of Exhibit A-3.

Agents” shall have the meaning assigned to such term in Article VIII.

Agreement” shall have the meaning assigned to such term in the preamble to this Agreement.

Agreement Value” shall mean, for each Hedging Agreement, taking into account the effect of any legally enforceable netting agreements relating thereto, (a) for any date of determination on or after the date such Hedging Agreement has been closed out and the termination value determined in accordance therewith, such termination value, and (b) for any date prior referenced in clause (a), the maximum aggregate amount that the Borrower or the applicable Subsidiary would be required to pay if such Hedging Agreement were terminated on such date.

Alternate Base Rate” shall mean, for any day, a rate per annum equal to the greatest of (a) the Prime Rate in effect on such day, (b) the Federal Funds Effective Rate in effect on such day plus 1/2 of 1% and (c) the one-month Adjusted LIBO Rate plus 1.00%; provided that for the purpose of clause (c), the Adjusted LIBO Rate for any day shall be based on the rate determined on such day at approximately 11:00 a.m. (London time) by reference to the British Bankers’ Association Interest Settlement Rates (or the successor thereto) for deposits in Dollars (as set

 

2


forth by any service selected by the Administrative Agent that has been nominated by the British Bankers’ Association (or the successor thereto) as an authorized vendor for the purpose of displaying such rates). If the Administrative Agent shall have determined (which determination shall be conclusive absent manifest error) that it is unable to ascertain the Federal Funds Effective Rate for any reason, including the inability or failure of the Administrative Agent to obtain sufficient quotations in accordance with the terms of the definition thereof, the Alternate Base Rate shall be determined without regard to clause (b) of the preceding sentence until the circumstances giving rise to such inability no longer exist. Any change in the Alternate Base Rate due to a change in the Prime Rate or the Federal Funds Effective Rate or Adjusted LIBO Rate shall be effective on the effective date of such change in the Prime Rate or the Federal Funds Effective Rate or Adjusted LIBO Rate, as the case may be.

Apollo” shall mean, collectively, Apollo Investment Corporation, Apollo Special Opportunities Managed Account, L.P., Apollo Centre Street Partnership, L.P. and Apollo SK Strategic Investments, L.P.

Applicable Margin” shall mean, for any day (a) with respect to any Eurodollar Loan, 6.75% per annum and (b) with respect to any ABR Loan, 5.75% per annum.

Applicable Premium” shall mean, with respect to any prepayment under Section 2.12, any prepayment or repayment following an Event of Default, or any mandatory assignment pursuant to Section 2.21 (other than any such mandatory assignment in connection with a Lender’s status as a Defaulting Lender), as applicable:

(a) if made prior to the first anniversary of the Closing Date, a cash amount equal to the product of 100% of the principal amount of the Loans prepaid, repaid or assigned times 2.00%;

(b) if made on or after the first anniversary of the Closing Date and before the second anniversary of the Closing Date, a cash amount equal to the product of 100% of the principal amount of the Loans prepaid, repaid or assigned times 1.00%;

(c) if made on or after the second anniversary of the Closing Date, $0.

Approved Counterparty” shall mean any Person whose long term senior unsecured debt rating at the time of entering into the Hedging Agreement is BBB/Baa2 by S&P or Moody’s (or their equivalent) or higher or any Person with an Affiliate whose long term senior unsecured debt rating at the time of entering into the Hedging Agreement is BBB/Baa2 by S&P or Moody’s (or their equivalent) or higher, so long as such Affiliate guarantees such Person’s obligations under the Hedging Agreement for the benefit of the applicable Loan Party party to such Hedging Agreement.

Approved Petroleum Engineers” shall mean Cawley Gillespie & Associates, Inc., Netherland, Sewell & Associates, Inc. and Ryder Scott Company Petroleum Consultants, L.P. or any other independent petroleum engineers selected by the Borrower and reasonably acceptable to the Administrative Agent.

 

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Arrangers” shall mean, collectively, CGMI, CS Securities and Global Hunter in their capacities as joint lead arrangers and joint bookrunners.

Asset Sale” shall mean the Disposition (by way of merger, casualty, condemnation or otherwise) by the Borrower or any of the Subsidiaries to any Person other than a Loan Party of any assets of such Person, including, without limitation, any Equity Interests held by such Person but excluding (a) sales of Hydrocarbons in the ordinary course of business; (b) so long as no Event of Default then exists or would result from such action, farm-outs, leases or other Dispositions of any of the Oil and Gas Properties not included in the determination of the then current PV-10 Value, so long as such farm-outs, leases and other Dispositions are for fair or reasonably equivalent value (as reasonably determined by the Borrower in its good faith business judgment); and (c) dispositions of claims against customers, working interest owners, other industry partners or any other Person in connection with workouts or bankruptcy, insolvency or other similar proceedings or collection or compromise of accounts receivable with respect thereto.

Assignment and Acceptance” shall mean an assignment and acceptance entered into by a Lender and an Eligible Assignee, in substantially the form of Exhibit A-1 or such other form as shall be approved by the Administrative Agent.

Board” shall mean the Board of Governors of the Federal Reserve System of the United States of America.

BOEM” shall mean the United States Department of Interior Bureau of Ocean Energy Management.

BOEM/BSEE” shall mean the collective reference to the BOEM/BSEE.

Borrower” shall have the meaning assigned to such term in the preamble to this Agreement.

Borrower Consolidated Group” has the meaning given such term in Section 6.06(f).

Borrower Group Payments” has the meaning given such term in Section 6.06(f).

Borrower Materials” shall have the meaning assigned to such term in Section 9.01.

Borrower Purchase Assignment and Acceptance” means a Borrower Purchase Assignment and Acceptance substantially in the form of Exhibit A-2.

Borrowing” shall mean any Initial Borrowing or any Incremental Borrowing.

Borrowing Request” shall mean a request by the Borrower in accordance with the terms of Section 2.03 and substantially in the form of Exhibit B, or such other form as shall be approved by the Administrative Agent.

Breakage Event” shall have the meaning assigned to such term in Section 2.16.

 

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BSEE” shall mean the United States Department of Interior Bureau of Safety and Environmental Enforcement.

Business Day” shall mean any day other than a Saturday, Sunday or day on which banks in New York City are authorized or required by law to close; provided, however, that when used in connection with a Eurodollar Loan, the term “Business Day” shall also exclude any day on which banks are not open for dealings in Dollar deposits in the London interbank market.

Calculation Date” shall mean each date on which any financial ratio calculation is calculated.

Capital Expenditures” shall mean, for any period, (a) the additions to property, plant and equipment and other capital expenditures of the Borrower and its Consolidated Subsidiaries that are (or are required to be) set forth in a consolidated statement of cash flows of the Borrower for such period prepared in accordance with GAAP and (b) Capital Lease Obligations or Synthetic Lease Obligations incurred by the Borrower and its Consolidated Subsidiaries during such period, but excluding in each case any such expenditure made to restore, replace or rebuild property to the condition of such property immediately prior to any damage, loss, destruction or condemnation of such property, to the extent such expenditure is made with insurance proceeds, condemnation awards or damage recovery proceeds relating to any such damage, loss, destruction or condemnation.

Capital Lease Obligations” of any Person shall mean the obligations of such Person to pay rent or other amounts under any lease of (or other arrangement conveying the right to use) real or personal property, or a combination thereof, which obligations are required to be classified and accounted for as capital or financing leases on a balance sheet of such Person under GAAP, and the amount of such obligations shall be the capitalized amount thereof determined in accordance with GAAP.

Cash Management Agreement” shall mean any agreement to provide Cash Management Services.

Cash Management Services” shall mean any one or more of the following types of services or facilities: (i) ACH transactions, (ii) treasury and/or cash management services, including, without limitation, controlled disbursement services, (iii) foreign exchange facilities, (iv) credit or debit cards, (v) deposit and other accounts and (vi) merchant services (other than those constituting a line of credit).

Casualty Event” shall mean any loss, casualty or other damage to, or any nationalization, taking under power of eminent domain or by condemnation or similar proceeding of, any Oil and Gas Property of the Borrower or any of its Subsidiaries having an estimated dollar amount in excess of 3.0% of the PV-10 Value as reflected in the most recently delivered Reserve Report.

CGMI” shall mean Citigroup Global Markets Inc., and its successors.

Change in Control” shall mean (a) prior to a Qualified IPO, the Permitted Investors shall cease to beneficially own and to have the power, directly or indirectly, to vote or direct the

 

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voting of, Voting Stock of Holdings representing at least 25% of the voting power of the total outstanding Voting Stock of Holdings, (b) after a Qualified IPO, the acquisition of “beneficial ownership” (as defined in Rules 13d-3 and 13d-5 under the Securities Exchange Act of 1934), directly or indirectly, by any “person” or “group” (within the meaning of the Securities Exchange Act of 1934 and the rules of the SEC thereunder, but excluding any employee benefit plan of such person and its Subsidiaries, and any person or entity acting in its capacity as trustee, agent or other fiduciary or administrator of any such plan), other than the Permitted Investors, Apollo, Highbridge, and any holder of Holdings Converted Equity Interests of more than the greater of (i) 35% of the outstanding Voting Stock of Holdings and (ii) the percentage of the outstanding Voting Stock of Holdings beneficially owned, directly or indirectly, by the Permitted Investors, Apollo, Highbridge, and any holder of Holdings Converted Equity Interests, or (c) Holdings (or any successor thereof as permitted by Section 6.21) shall cease to beneficially own, directly or indirectly, 100% of the issued and outstanding Equity Interests of the Borrower.

Change in Law” shall mean (a) the adoption of any law, rule, regulation or treaty after the Closing Date, (b) any change in any law, rule, regulation or treaty or in the administration, interpretation, implementation or application thereof by any Governmental Authority after the Closing Date or (c) compliance by any Lender (or, for purposes of Section 2.14, by any lending office of such Lender or by such Lender’s holding company, if any) with any request, guideline or directive (whether or not having the force of law) of any Governmental Authority made or issued after the Closing Date; provided that notwithstanding anything herein to the contrary, (x) the Dodd-Frank Wall Street Reform and Consumer Protection Act and all requests, rules, guidelines or directives thereunder or issued in connection therewith and (y) all requests, rules, guidelines or directives promulgated by the Bank for International Settlements, the Basel Committee on Banking Supervision (or any successor or similar authority) or the United States or foreign regulatory authorities, in each case pursuant to Basel III, shall in each case be deemed to be a “Change in Law”, regardless of the date enacted, adopted or issued.

Charges” shall have the meaning assigned to such term in Section 9.09.

Chesapeake Note” shall mean Holdings’ subordinated unsecured note dated as of April 8, 2013, payable to Chesapeake Exploration, L.L.C.

Closing Date” shall mean the date on which the conditions specified in Section 4.01 are satisfied (or waived in accordance with Section 9.08).

Code” shall mean the Internal Revenue Code of 1986, as amended from time to time.

Collateral” shall mean all present and after-acquired personal and real property of the Loan Parties (including the Mortgaged Properties), in which Liens are purported to be granted pursuant to any Security Document as security for the Obligations.

Collateral Agent” shall have the meaning assigned to such term in the preamble to this Agreement.

Commitment” shall mean, with respect to each Lender, its Initial Commitment and/or its Incremental Commitment.

 

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Commodity Exchange Act” shall mean the Commodity Exchange Act (7 U.S.C. § 1 et seq.), as amended from time to time, and any successor statute.

Communications” shall have the meaning assigned to such term in Section 9.01.

Connection Income Taxes” shall mean Other Connection Taxes that are imposed on or measured by net income (however denominated) or that are franchise Taxes or branch profits Taxes.

Consolidated EBITDAX” shall mean, for any period, the sum of Consolidated Net Income for such period plus the following expenses or charges to the extent deducted from Consolidated Net Income in such period: (a) interest, income taxes, depreciation, depletion, amortization (including non-cash amortization of deferred financing costs), exploration expenses, accretion of asset retirement obligations, and other similar non-cash charges (including non-cash expenses relating to stock-based compensation and hedging, but excluding any non-cash charge to the extent it represents an accrual of or reserve for cash expenditures in any future period), (b) any reasonable expenses and charges related to any Investment, acquisition, Disposition, offering of Equity Interests, recapitalization, or issuance or incurrence of Indebtedness not prohibited hereunder (in each case, whether or not successful) and (c) the Transaction Costs, minus all non-cash income (excluding any non-cash income to the extent it represents the reversal of an accrual of or reserve for a potential cash item in any prior period) included in the calculation of Consolidated Net Income; provided, however, that if the Borrower or any of the Consolidated Subsidiaries shall have consummated any acquisition or disposition during such period, Consolidated EBITDAX shall be calculated after giving effect to any applicable Pro Forma Adjustments. Consolidated EBITDAX (x) for the four consecutive fiscal quarters ending on September 30, 2014, shall equal Consolidated EBITDAX during the period from July 1, 2014 through September 30, 2014 multiplied by four (4), (y) for the four consecutive fiscal quarters ending on December 31, 2014, shall equal Consolidated EBITDAX during the period from July 1, 2014 through December 31, 2014 multiplied by two (2), and (z) for the four consecutive fiscal quarters ending on March 31, 2015, shall equal Consolidated EBITDAX during the period from July 1, 2014 through March 31, 2015 multiplied by 4/3.

Consolidated Interest Expense” shall mean, for any period and without duplication, the sum of (a) the interest expense (including imputed interest expense in respect of Capital Lease Obligations and Synthetic Lease Obligations) of the Borrower and the Consolidated Subsidiaries for such period, determined on a consolidated basis in accordance with GAAP, plus (b) any interest accrued during such period in respect of Indebtedness of the Borrower or any Consolidated Subsidiary that is required to be capitalized rather than included in consolidated interest expense for such period in accordance with GAAP. For purposes of the foregoing, interest expense shall be determined after giving effect to any net payments made or received by the Borrower or any Subsidiary with respect to interest rate Hedging Agreements.

Consolidated Net Income” shall mean, for any period, the net income or loss of the Borrower and the Consolidated Subsidiaries for such period determined on a consolidated basis in accordance with GAAP; provided that there shall be excluded from such net income (or loss) (to the extent otherwise included therein) the following: (a) the net income (or loss) of any Person in which the Borrower or any Consolidated Subsidiary has an interest (which interest

 

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does not cause the net income of such other Person to be consolidated with the net income of the Borrower and the Consolidated Subsidiaries in accordance with GAAP), except to the extent of the amount of dividends or distributions actually paid in cash during such period by such other Person to the Borrower or to a Consolidated Subsidiary, as the case may be; (b) the net income (but not loss) during such period of any Consolidated Subsidiary to the extent that the declaration or payment of dividends or similar distributions or transfers or loans by that Consolidated Subsidiary is not at the time permitted by operation of the terms of its charter or any agreement, instrument or Governmental Requirement applicable to such Consolidated Subsidiary or is otherwise consensually restricted or prohibited; (c) any extraordinary non-cash gains or losses during such period; (d) non-cash gains, losses or adjustments, including non-cash gains, losses or adjustments under authoritative guidance from the FASB as a result of changes in the fair market value of derivatives and any gains or losses attributable to writeups or writedowns of assets, including ceiling test writedowns and writedowns under authoritative guidance from the FASB as a result of accounting for oil and gas activities, goodwill and other intangible assets, and property, plant and equipment (for the avoidance of doubt, realized gains or losses will be counted in Consolidated Net Income in the quarter that cash is actually received or paid); (e) any non-cash employee based compensation; (f) any gain or loss realized in connection with asset sales outside the ordinary course of business; (g) the income or loss of any Person accrued prior to the date it becomes a Subsidiary or is merged into or consolidated with the Borrower or any Subsidiary or the date that such Person’s assets are acquired by the Borrower or any Subsidiary and (h) any income or loss attributable to the early extinguishment of Indebtedness.

Consolidated Return” has the meaning given such term in Section 6.06(f).

Consolidated Subsidiaries” means each Subsidiary of the Borrower (whether now existing or hereafter created or acquired) the financial statements of are (or should be) consolidated with the financial statements of the Borrower in accordance with GAAP.

Constellation Agreement” means the Purchase and Sale Agreement dated as of August 23, 2012 between Energy & Exploration Partners, LLC and CEU Huntsville, LLC, amended prior to the date hereof.

Consultant Overrides” means conveyances of royalties, overriding royalty interests and net profits interests granted to certain consultants and other service providers to the Borrower and its Subsidiaries; provided such conveyances are on terms usual and customary for the oil and gas business and in no event burden a material portion of the Borrower’s or the applicable Subsidiary’s Hydrocarbon production.

Control” shall mean the possession, directly or indirectly, of the power to direct or cause the direction of the management or policies of a Person, whether through the ownership of Voting Stock, by contract or otherwise, and the terms “Controlling” and “Controlled” shall have meanings correlative thereto.

Credit Facility” shall mean collectively, the Commitments and the Loans made hereunder.

 

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Credit Suisse” shall have the meaning assigned to such term in the preamble to this Agreement.

CS Securities” shall mean Credit Suisse Securities (USA) LLC, and its successors.

Cure Amount” shall have the meaning assigned to such term in Section 7.02(a).

Cure Right” shall have the meaning assigned to such term in Section 7.02(a).

Current Assets” shall mean, at any time, the consolidated current assets (other than cash and Permitted Investments) of the Borrower and the Subsidiaries, but excluding the current portion of current and deferred income tax assets.

Current Liabilities” shall mean, at any time, the consolidated current liabilities of the Borrower and the Subsidiaries at such time, but excluding the current liabilities in respect of Indebtedness (including all Indebtedness consisting of Loans), the current portion of current and deferred income taxes, and the current portion of deferred revenues.

Debtor Relief Laws” shall mean, collectively, Title 11 of the United States Code entitled “Bankruptcy” and any other bankruptcy, insolvency, liquidation, restructuring, reorganization, compromise, arrangement, readjustment of debt, conservatorship, receivership, winding-up, dissolution, or similar laws of the United States and any other applicable jurisdictions from time to time in effect.

Default” shall mean any event or condition which upon notice, lapse of time or both would constitute an Event of Default.

Defaulting Lender” shall mean any Lender that (a) has failed to pay to the Administrative Agent or any other Lender any other amount required to be paid by it hereunder within two Business Days of the date when due, or (b) has, or has a direct or indirect parent company that has, (i) become the subject of a proceeding under any Debtor Relief Law, or (ii) had appointed for it a receiver, custodian, conservator, trustee, administrator, assignee for the benefit of creditors or similar Person charged with reorganization or liquidation of its business or assets, including the Federal Deposit Insurance Corporation or any other state or Federal regulatory authority acting in such a capacity; provided that a Lender shall not be a Defaulting Lender solely by virtue of the ownership or acquisition of any Equity Interest in that Lender or any direct or indirect parent company thereof by a Governmental Authority so long as such ownership interest does not result in or provide such Lender with immunity from the jurisdiction of courts within the United States or from the enforcement of judgments or writs of attachment on its assets or permit such Lender (or such Governmental Authority) to reject, repudiate, disavow or disaffirm any contracts or agreements made with such Lender. Any determination by the Administrative Agent that a Lender is a Defaulting Lender under clauses (a) or (b) above shall be conclusive and binding absent manifest error, and such Lender shall be deemed to be a Defaulting Lender (subject to Section 2.22(b)) upon delivery of written notice of such determination to the Borrower and each Lender.

Disposition” shall mean, with respect to any property, any sale, assignment, conveyance, transfer or other disposition (including by way of a merger or consolidation) of such

 

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property; and the terms “Dispose” and “Disposed of” shall have correlative meanings; provided that “Disposition”, “Dispose” and “Disposed of” shall not be deemed to include any issuance by a Person of any of its Equity Interests to another Person.

Disqualified Lender” shall mean any (i) competitor of the Borrower or any of its Subsidiaries, (ii) such other Person, in each case, identified in writing to the Arrangers on or prior to the Closing Date, and (iii) the reasonably identified Affiliates of any of the foregoing; provided that, after the Closing Date, the Borrower shall be permitted, upon reasonable notice to the Administrative Agent, to supplement the list of competitors provided for in clause (i) to include additional competitors and/or any Affiliates thereof (such list, as so supplemented from time to time, the “Disqualified Institution List”); provided, further, that no supplement may operate to exclude any Person that is a Lender. The Administrative Agent will make available to a Lender, upon the request of such Lender, the Disqualified Institution List.

Disqualified Stock” shall mean any Equity Interest that, by its terms (or by the terms of any security into which it is convertible or for which it is exchangeable), or upon the happening of any event, (a) matures (excluding any maturity as the result of an optional redemption by the issuer thereof) or is mandatorily redeemable (other than solely for Qualified Capital Stock), pursuant to a sinking fund obligation or otherwise (except as a result of a change of control, public equity offering or asset sale so long as any rights of the holders thereof upon the occurrence of a change of control, public equity offering or asset sale event shall be subject to the prior repayment in full of the Loans and all other Obligations that are accrued and payable and the termination of the Commitments in accordance with the terms hereof), or is redeemable at the option of the holder thereof (other than solely for Qualified Capital Stock), in whole or in part, or requires the payment of any cash dividend or any other scheduled payment constituting a return of capital, in each case at any time prior to the date that is 91 days after the Maturity Date, or (b) is convertible into or exchangeable (unless at the sole option of the issuer thereof) for (i) debt securities or (ii) any Equity Interest referred to in clause (a) above, in each case at any time prior to the date that is 91 days after the Maturity Date.

Domestic Subsidiaries” shall mean all Subsidiaries incorporated or organized under the laws of the United States of America, any State thereof or the District of Columbia or that Guarantee or otherwise provide direct credit support for any Indebtedness of the Borrower.

Eligible Assignee” shall mean (a) a Lender, (b) an Affiliate of a Lender, (c) a Related Fund of a Lender, (d) the Borrower (solely pursuant to Section 9.04(k)), (e) Holdings (solely pursuant to Section 9.04(k)), (f) any Affiliated Lender (solely pursuant to Section 9.04(l)) and (g) any other Person (other than a natural person) approved by (i) the Administrative Agent and (ii) unless an Event of Default pursuant to Section 7.01(b), (c), (g) or (h) has occurred and is continuing, the Borrower (each such approval not to be unreasonably withheld or delayed); provided that notwithstanding the foregoing, “Eligible Assignee” shall not include the Permitted Investors, any of the Borrower’s Affiliates (other than Holdings (subject to Section 9.04(k)) and any Affiliated Lender (subject to Section 9.04(l)) or any Disqualified Lender.

Environmental Laws” shall mean all Federal, state, local and foreign laws (including common law), treaties, regulations, rules, ordinances, codes, decrees, judgments, directives, orders (including consent orders), in each case, relating to protection of the environment, natural

 

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resources, occupational health and safety (to the extent related to exposure to toxic or hazardous substances or wastes) or the presence, Release of, or exposure to, toxic or hazardous substances or wastes.

Environmental Liability” shall mean all liabilities, obligations, damages, losses, claims, actions, suits, judgments, orders, fines, penalties, fees, expenses and costs (including administrative oversight, consultant and attorney costs, capital and operating costs, costs associated with financial assurance, permitting or closure requirements, natural resource damages and monitoring or remediation costs), whether contingent or otherwise, arising out of or relating to (a) compliance or non-compliance with any Environmental Law, (b) the generation, use, handling, transportation, storage, treatment or disposal of any Hazardous Materials, (c) exposure to any Hazardous Materials, (d) the presence or Release or threatened Release of any Hazardous Materials or (e) any contract, agreement or other consensual arrangement pursuant to which liability is assumed or imposed with respect to any of the foregoing.

Equity Interests” shall mean shares of capital stock, partnership interests, membership interests in a limited liability company, beneficial interests in a trust or other equity interests or equivalent ownership interests (however designated) in any Person, and any option, warrant or other right entitling the holder thereof to purchase or otherwise acquire any such equity interest.

Equity Issuance” shall mean any issuance or sale by the Borrower or any of its Subsidiaries of any Equity Interests of the Borrower or any such Subsidiary, as applicable.

ERISA” shall mean the Employee Retirement Income Security Act of 1974, as the same may be amended from time to time.

ERISA Affiliate” shall mean any trade or business (whether or not incorporated) that, together with the Borrower, is treated as a single employer under Section 414(b) or (c) of the Code, or solely for purposes of Section 302 of ERISA and Section 412 of the Code, is treated as a single employer under Section 414 of the Code.

ERISA Event” shall mean (a) any “reportable event”, as defined in Section 4043 of ERISA or the regulations issued thereunder, with respect to a Plan (other than an event for which the 30-day notice period is waived), (b) any failure by any Plan to satisfy the minimum funding standard (within the meaning of Section 412 of the Code or Section 302 of ERISA) applicable to such Plan, whether or not waived, (c) the filing pursuant to Section 412(c) of the Code or Section 302(c) of ERISA of an application for a waiver of the minimum funding standard with respect to any Plan, (d) a determination that any Plan is in “at risk” status (as defined in Section 303(i)(4) of ERISA or Section 430(i)(4) of the Code), (e) the incurrence by the Borrower or any of its ERISA Affiliates of any liability under Title IV of ERISA with respect to the termination of any Plan or the withdrawal or partial withdrawal of the Borrower or any of its ERISA Affiliates from any Plan subject to Section 4063 of ERISA for which it is a substantial employer or Multiemployer Plan, (f) the receipt by the Borrower or any of its ERISA Affiliates from the PBGC or a plan administrator of any notice relating to the intention to terminate any Plan or Plans or to appoint a trustee to administer any Plan, (g) the receipt by the Borrower or any of its ERISA Affiliates of any notice, or the receipt by any Multiemployer Plan from the Borrower or any of its ERISA Affiliates of any notice, concerning the imposition of Withdrawal Liability or a

 

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determination that a Multiemployer Plan is, or is expected to be, insolvent or in reorganization, within the meaning of Title IV of ERISA, (i) the occurrence of a “prohibited transaction” with respect to which the Borrower or any of the Subsidiaries is a “disqualified person” (within the meaning of Section 4975 of the Code) or with respect to which the Borrower or any such Subsidiary could otherwise be liable or (j) any other event or condition with respect to a Plan or Multiemployer Plan that could result in a reasonable expectation or actual imposition of any liability under Title IV of ERISA, other than for PBGC premiums due but not delinquent under Section 4007 of ERISA, upon the Borrower or any Subsidiary.

Eurodollar”, when used in reference to any Loan or Borrowing, refers to whether such Loan, or the Loans comprising such Borrowing, are bearing interest at a rate determined by reference to the Adjusted LIBO Rate.

Events of Default” shall have the meaning assigned to such term in Section 7.01.

Excepted Liens” shall mean (a) Liens for Taxes, assessments or other governmental charges or levies which are not yet due or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with GAAP; (b) Liens in connection with workers’ compensation, unemployment insurance or other social security, old age pension or public liability obligations which are not delinquent by more than 30 days or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with GAAP; (c) landlord’s liens, operators’, vendors’, carriers’, warehousemen’s, repairmen’s, mechanics’, suppliers’, workers’, materialmen’s, construction or other like Liens arising by operation of law or otherwise in the ordinary course of business or incident to the exploration, development, operation and maintenance of Oil and Gas Properties each of which is in respect of obligations that are not delinquent by more than 30 days or which are being contested in good faith by appropriate action and for which adequate reserves have been and are maintained in accordance with GAAP; (d) contractual Liens which arise in the ordinary course of business under operating agreements, joint venture agreements, oil and gas partnership agreements, oil and gas leases, farm-out and farm-in agreements, division orders, contracts for the sale, transportation or exchange of oil and natural gas, unitization and pooling declarations and agreements, area of mutual interest agreements, marketing agreements, processing agreements, development agreements, gas balancing or deferred production agreements, injection, repressuring and recycling agreements, salt water or other disposal agreements, seismic or other geophysical permits or agreements, and other agreements which are usual and customary in the oil and gas exploration, development or extraction business and are for claims which are not delinquent by more than 30 days or which are being contested in good faith by appropriate action and for which adequate reserves have been maintained in accordance with GAAP, provided that any such Lien referred to in this clause does not materially impair the use of the property covered by such Lien for the purposes for which such property is held by the Borrower or any Subsidiary or materially impair the value of such property subject thereto; (e) Liens arising solely by virtue of any statutory or common law provision or any deposit account agreement or similar agreement relating to banker’s liens, rights of set-off or similar rights and remedies and burdening only deposit accounts, commodity accounts or other funds maintained with a creditor depository institution or commodity trader or broker, provided that no such deposit account is a dedicated cash collateral account or is subject to restrictions against access by the depositor in excess of those set forth by regulations

 

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promulgated by the Board and no such deposit account or commodity account is intended by Borrower or any of its Subsidiaries to provide collateral to the depository institution; (f) easements, restrictions, servitudes, permits, conditions, covenants, exceptions or reservations in any property of the Borrower or any Subsidiary for the purpose of roads, pipelines, transmission lines, transportation lines, distribution lines for the removal of gas, oil, coal or other minerals or timber, and other like purposes, or for the joint or common use of real estate, rights of way, facilities and equipment, that do not secure any monetary obligations and which in the aggregate do not materially impair the use of such property for the purposes for which such property is held by the Borrower or any Subsidiary or materially impair the value of such property subject thereto; (g) Liens on cash or securities pledged to secure insurance premiums or insurance reimbursements or insurance obligations or performance of tenders, surety and appeal bonds, government contracts, performance and return of money bonds, bids, trade contracts, leases, statutory obligations, regulatory obligations and other obligations of a like nature incurred in the ordinary course of business, (h) judgment and attachment Liens not giving rise to an Event of Default, provided that any appropriate legal proceedings which may have been duly initiated for the review of such judgment shall not have been finally terminated or the period within which such proceeding may be initiated shall not have expired and no action to enforce such Lien has been commenced, (i) encumbrances consisting of deed restrictions, zoning restrictions, and other similar restrictions on the use of Oil and Gas Properties, none of which, in the aggregate, materially impairs the use of such property by the Borrower or any other Loan Party in the operation of its business or materially detracts from the value of such properties, and none of which, in the aggregate, is or shall be violated in any material respect by existing proposed operations; (j) purported Liens evidenced by the filing of UCC financing statements solely as a precautionary measure in connection with operating leases of personal property; (k) minor defects and irregularities of title to any property so long as such defects and irregularities, in the aggregate, neither secure Indebtedness nor materially impair the value of such property or the use of such property for the purposes for which the property is held; (l) Liens on cash earnest money deposited pursuant to the terms of an agreement to acquire assets used in, or Persons engaged in, the oil and gas business, as permitted by this Agreement; (m) Liens arising out of conditional sale, title retention, consignment or similar arrangements for the sale of goods entered into by any Loan Party in the ordinary course of business, consistent with the past practices of such Loan Party and as customary in the oil and gas industry; (n) lease burdens on Oil and Gas Properties not permitted under Section 6.02(g) that, to the extent they burden PDP Reserves, are or will be deducted in the calculation of engineered discounted present value in the Reserve Report; (o) leases, licenses, subleases or sublicenses granted to others in the ordinary course of business which do not (i) interfere in any material respect with the business of the Borrower or any Subsidiary or (ii) secure any Indebtedness; (p) Liens in favor of customs and revenue authorities arising as a matter of law to secure payment of customs duties in connection with the importation of goods in the ordinary course of business; and (q) Liens encumbering reasonable customary initial deposits and margin deposits and similar Liens attaching to commodity trading accounts or other brokerage accounts incurred in the ordinary course of business and not for speculative purposes.

Excess Cash Flow” shall mean, for any fiscal year of the Borrower, the excess of (a) the sum, without duplication, of (i) Consolidated EBITDAX for such fiscal year and (ii) reductions to non-cash working capital of the Borrower and the Subsidiaries for such fiscal year (i.e. the decrease, if any, in Current Assets minus Current Liabilities from the beginning to the end of

 

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such fiscal year (except as a result of the reclassification of items from short-term to long-term or vice versa)) over (b) the sum, without duplication, of (i) the amount of any Taxes payable in cash by the Borrower and the Subsidiaries during such fiscal year, (ii) Consolidated Interest Expense paid in cash during such fiscal year, (iii) Capital Expenditures made in cash during such fiscal year to the extent financed with Internally Generated Cash, (iv) permanent repayments of Indebtedness (including the principal component of payments in respect of Capital Lease Obligations but excluding all prepayments of Loans under Section 2.12 and 2.13 and purchases of Loans under Section 9.04(k)) made in cash by Holdings, the Borrower and the Consolidated Subsidiaries during such fiscal year, but only to the extent (x) financed with Internally Generated Cash and (y) that the Indebtedness so prepaid by its terms cannot be reborrowed or redrawn, (v) additions to non-cash working capital for such fiscal year (i.e. the increase, if any, in Current Assets minus Current Liabilities from the beginning to the end of such fiscal year (except as a result of the reclassification of items from short-term to long-term or vice versa)), (vi) cash payments by the Borrower and the Subsidiaries during such fiscal year in respect of long-term liabilities of the Borrower and the Subsidiaries other than Indebtedness to the extent financed with Internally Generated Cash, (vii) without duplication of amounts deducted pursuant to clause (x) below in prior fiscal years, the amount of Investments and Permitted Acquisitions to the extent financed with Internally Generated Cash during such fiscal year, (viii) the aggregate amount of expenditures actually made by the Borrower and the Subsidiaries in cash during such fiscal year (including expenditures for the payment of financing fees) to the extent that such expenditures are not expensed during such period and are financed with Internally Generated Cash, (ix) the aggregate amount of any premium, make-whole or penalty payments actually paid in cash by the Borrower and the Subsidiaries during such fiscal year that are required to be made in connection with any prepayment of Indebtedness to the extent financed with Internally Generated Cash, (x) the amount (without duplication) of Restricted Payments paid by the Borrower during such period pursuant to Sections 6.06(e) and 6.06(f) to the extent financed with Internally Generated Cash, and (xi) without duplication of amounts deducted from Excess Cash Flow in prior periods, the aggregate consideration required to be paid in cash by the Borrower or any of the Subsidiaries pursuant to binding contracts (the “Contract Consideration”) entered into prior to or during such fiscal year relating to Permitted Acquisitions or Capital Expenditures to be consummated or made during the first fiscal quarter following the end of such fiscal year to the extent intended to be financed with Internally Generated Cash, provided that to the extent the aggregate cash consideration paid for such Permitted Acquisitions or Capital Expenditures during such fiscal-quarter period is less than the Contract Consideration, the amount of such shortfall, less the amount financed other than through Internally Generated Cash, shall be added to the calculation of Excess Cash Flow for the fiscal year immediately following such fiscal year.

Excluded Taxes” shall mean any of the following Taxes imposed on or with respect to a Recipient or required to be withheld or deducted from a payment to a Recipient, (a) Taxes imposed on or measured by net income (however denominated), franchise Taxes, and branch profits Taxes, in each case, (i) imposed as a result of such Recipient being organized under the laws of, or having its principal office or, in the case of any Lender, its applicable lending office located in, the jurisdiction imposing such Tax (or any political subdivision thereof) or (ii) that are Other Connection Taxes, (b) in the case of a Lender, U.S. Federal withholding Taxes imposed on amounts payable to or for the account of such Lender with respect to an applicable interest in a Loan or Commitment pursuant to a law in effect on the date on which (i) such Lender acquires such interest in the Loan or Commitment (other than pursuant to an assignment request by the

 

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Borrower under Section 2.21(a)) or (ii) such Lender changes its applicable lending office, except in each case to the extent that, pursuant to Section 2.20, amounts with respect to such Taxes were payable either to such Lender’s assignor immediately before such Lender acquired the applicable interest in such Loan or Commitment or to such Lender immediately before it changed its applicable lending office, (c) Taxes attributable to such Recipient’s failure to comply with Section 2.20(e) and (d) any U.S. Federal withholding Taxes imposed under FATCA.

Existing Debt” shall have the meaning assigned to such term in the recitals hereto.

Facility” shall mean each Initial Facility and/or any or all of the Incremental Facilities providing for Other Term Loans.

FATCA” shall mean Sections 1471 through 1474 of the Code, as of the date of this Agreement (or any amended or successor version that is substantively comparable and not materially more onerous to comply with), any current or future regulations or official interpretations thereof, any agreements entered into pursuant to Section 1471(b)(1) of the Code and any intergovernmental agreements entered into by the United States that implement or modify the foregoing (together with the portions of any law implementing such intergovernmental agreements).

FCPA” shall have the meaning assigned to such term in Section 3.23.

Federal Funds Effective Rate” shall mean, for any day, the weighted average of the rates on overnight Federal funds transactions with members of the Federal Reserve System arranged by Federal funds brokers, as published on the next succeeding Business Day by the Federal Reserve Bank of New York, or, if such rate is not so published for any day that is a Business Day, the average of the quotations for the day for such transactions received by the Administrative Agent from three Federal funds brokers of recognized standing selected by it.

Fees” shall mean the Administrative Agent Fees and any other fees set forth in any separate writing between the Borrower and any agent or arranger hereunder.

Financial Officer” of any Person shall mean the chief financial officer, principal accounting officer, treasurer or controller of such Person.

Financial Performance Covenant” shall have the meaning assigned to such term in Section 7.02(a).

Forecasted Proved Reserve Production” shall mean, for any period, the forecasted production of crude oil or natural gas (measured by barrel of oil equivalent, not sales price) for such period from the Borrower’s and the Subsidiary Guarantors’ Proved Reserves, as forecasted in the most recent Reserve Report delivered pursuant to this Agreement, after deducting forecasted production from any Oil and Gas Properties sold or under contract for sale that had been included in such report.

Foreign Lender” shall mean any Lender that is not a U.S. Person.

Foreign Subsidiary” shall mean any Subsidiary that is not a Domestic Subsidiary.

 

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Fund” shall mean any Person (other than a natural Person) that is engaged in making, purchasing, holding or otherwise investing in commercial loans and similar extensions of credit in the ordinary course of its activities.

GAAP” shall mean United States generally accepted accounting principles, as in effect from time to time; provided, however, that if the Borrower notifies the Administrative Agent that the Borrower requests an amendment to any provision hereof to eliminate the effect of any change occurring after the Closing Date in GAAP or in the application thereof on the operation of such provision (or if the Administrative Agent notifies the Borrower that the Required Lenders request an amendment to any provision hereof for such purpose), regardless of whether any such notice is given before or after such change in GAAP or in the application thereof, then such provision shall be interpreted on the basis of GAAP as in effect and applied immediately before such change shall have become effective until such notice shall have been withdrawn or such provision amended in accordance herewith.

Global Hunter” shall mean Global Hunter Securities, LLC, together with its affiliate, Sea Port Group Securities LLC, and their respective successors.

Governmental Authority” shall mean any Federal, state, local or foreign court or governmental agency, authority, instrumentality or, regulatory body, court, central bank or other entity exercising executive, legislative, judicial, taxing, regulatory or administrative powers or functions of or pertaining to government (including any supra-national bodies such as the European Union or the European Central Bank).

Governmental Requirement” means any law, statute, code, ordinance, order, determination, rule, regulation, judgment, decree, injunction, franchise, permit, certificate, license, authorization or other directive or requirement, whether now or hereinafter in effect, of any Governmental Authority.

Granting Lender” shall have the meaning assigned to such term in Section 9.04(i).

Guarantee” of or by any Person shall mean any obligation, contingent or otherwise, of such Person guaranteeing or having the economic effect of guaranteeing any Indebtedness or other obligation of any other Person (the “primary obligor”) in any manner, whether directly or indirectly, and including any obligation of such Person, direct or indirect, (a) to purchase or pay (or advance or supply funds for the purchase or payment of) such Indebtedness or other obligation or to purchase (or to advance or supply funds for the purchase of) any security for the payment of such Indebtedness or other obligation, (b) to purchase or lease property, securities or services for the purpose of assuring the owner of such Indebtedness or other obligation of the payment of such Indebtedness or other obligation or (c) to maintain working capital, equity capital or any other financial statement condition or liquidity of the primary obligor so as to enable the primary obligor to pay such Indebtedness or other obligation; provided, however, that the term “Guarantee” shall not include endorsements for collection or deposit in the ordinary course of business.

Guarantee and Collateral Agreement” shall mean the Guarantee and Collateral Agreement dated as of the date hereof, among the Borrower, Holdings, the Subsidiary Guarantors and the Collateral Agent, as the same may be amended, modified or supplemented from time to time.

 

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Guarantors” shall mean Holdings and the Subsidiary Guarantors.

Guggenheim Overrides” means conveyances of overriding royalty interests granted by Energy & Exploration Partners, LLC to Guggenheim Corporate Funding, LLC pursuant to that certain Overriding Royalty Interest Conveyance dated June 26, 2012 as in effect on the Closing Date.

Hazardous Materials” shall mean (a) any petroleum products or byproducts and all other Hydrocarbons, coal ash, radon gas, asbestos, urea formaldehyde foam insulation, polychlorinated biphenyls, chlorofluorocarbons and all other ozone-depleting substances and (b) any chemical, material, substance or waste that is prohibited, limited or regulated by or pursuant to any Environmental Law.

Hedging Agreement” shall mean any interest rate protection agreement, foreign currency exchange agreement, commodity price protection agreement or other interest or currency exchange rate or commodity price hedging arrangement (including puts, floors and basis differential swaps).

Highbridge” shall mean, collectively, Highbridge Principal Strategies, LLC, Highbridge Principal Strategies – Mezzanine Partners II Delaware Subsidiary, LLC, Highbridge Principal Strategies – AP Mezzanine Partners II, L.P., ENXP Offshore, L.P., and ENXP Institutional, L.P.

Holdings” shall have the meaning assigned to such term in the preamble to this Agreement.

Holdings Converted Equity Interests” shall mean Equity Interests of Holdings that were converted thereto from Holdings Notes pursuant to the terms of the Holdings Notes upon the consummation of a Qualified IPO.

Holdings Notes” shall mean Holdings’ 8% convertible subordinated notes due 2019 in an aggregate principal amount equal to $375,000,000.

Holdings Notes Documents” shall mean the indenture dated as of the date hereof among Holdings, as issuer, and the trustee identified therein, pursuant to which the Holdings Notes were issued, the Holdings Notes, and all other instruments, agreements and other documents evidencing the Holdings Notes (including, without limitation, any registration rights agreements) or providing for any guarantee or other right in respect thereof.

Hydrocarbon Interests” shall mean all rights, titles, interests and estates now or hereafter acquired in and to oil and gas leases, oil, gas and mineral leases, or other liquid or gaseous hydrocarbon leases, mineral fee interests, overriding royalty and royalty interests, net profit interests and production payment interests, including any reserved or residual interests of whatever nature.

 

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Hydrocarbons” shall mean oil, gas, casinghead gas, drip gasoline, natural gasoline, condensate, distillate, liquid hydrocarbons, gaseous hydrocarbons and all products refined or separated therefrom.

Increased Amount Date” shall have the meaning assigned to such term in Section 2.23(a).

Incremental Amount” shall mean, at any time, an amount not to exceed the excess, if any, of (i) the sum of $175,000,000 and the amount of all voluntary prepayments of, and purchases by the Borrower or Holdings pursuant to Section 9.04(k) of, the Loans effected after the Closing Date and prior to the Increased Amount Date over (ii) the aggregate principal amount of all Incremental Commitments established after the Closing Date pursuant to Section 2.23.

Incremental Assumption Agreement” shall mean an Incremental Assumption Agreement in form and substance reasonably satisfactory to the Administrative Agent, among the Borrower, the Administrative Agent and one or more Incremental Lenders.

Incremental Borrowing” shall mean a borrowing comprised of Incremental Loans of the same Type made, converted or continued on the same date and, in the case of Eurodollar Loans, as to which a single Interest Period is in effect.

Incremental Commitment” shall mean the commitment of any Lender, established pursuant to Section 2.23, to make Incremental Loans to the Borrower as set forth in Section 2.01(b), as the same may be reduced or increased from time to time pursuant to assignments by or to such Lender pursuant to Section 9.04.

Incremental Facility” shall mean any series of Incremental Loans established pursuant to an Incremental Assumption Agreement.

Incremental Lender” shall mean a Lender with an Incremental Commitment or an outstanding Incremental Loan.

Incremental Loan Maturity Date” shall mean, with respect to any series or tranche of Incremental Loans established pursuant to an Incremental Assumption Agreement, the maturity date as set forth in such Incremental Assumption Agreement.

Incremental Loans” shall mean term loans made by one or more Lenders to the Borrower pursuant to Section 2.01(b). Incremental Loans may be made in the form of additional term loans having the same terms as the Initial Loans or, to the extent permitted by Section 2.23 and provided for in the relevant Incremental Assumption Agreement, Other Term Loans.

Indebtedness” of any Person shall mean (without duplication): (a) all obligations of such Person for borrowed money or evidenced by bonds, bankers’ acceptances, debentures, notes or other similar instruments; (b) all obligations of such Person (whether contingent or otherwise) in respect of letters of credit, surety or other bonds and similar instruments; (c) all accrued expenses, liabilities or other obligations of such Person to pay the deferred purchase price of property or services (other than any earn-out obligation (until such obligation becomes a liability

 

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on the balance sheet of such Person in accordance with GAAP) and liabilities of such Person to trade creditors arising in the ordinary course of business (including guarantees thereof or instruments evidencing such liabilities)); (d) the principal component of Capital Lease Obligations; (e) all obligations under Synthetic Leases; (f) all Indebtedness (as defined in the other clauses of this definition) of others secured by (or for which the holder of such Indebtedness has an existing right, contingent or otherwise, to be secured by) a Lien on any property of such Person, whether or not such Indebtedness is assumed by such Person; (g) all Indebtedness (as defined in the other clauses of this definition) of others Guaranteed by such Person or in which such Person otherwise assures a creditor against loss of the Indebtedness (howsoever such assurance shall be made) to the extent of the lesser of the amount of such Indebtedness and the maximum stated amount of such Guarantee or assurance against loss; (h) [reserved]; (i) obligations to deliver commodities, goods or services, including, without limitation, Hydrocarbons, in consideration of one or more advance payments, other than gas balancing agreements in the ordinary course of business; (j) [reserved]; (k) any Indebtedness of a partnership for which such Person is liable either by agreement, by operation of law or by a Governmental Requirement but only to the extent of such liability; (l) Disqualified Stock; (m) the undischarged balance of any production payment created by such Person or for the creation of which such Person directly or indirectly received payment and (n) the net obligations of such Person under any Hedging Agreement. The Indebtedness of any Person shall include all obligations of such Person of the character described above to the extent such Person remains legally liable in respect thereof notwithstanding that any such obligation is not included as a liability of such Person under GAAP.

For the avoidance of doubt, “Indebtedness” does not include indemnities incurred in the ordinary course of business or in connection with the disposition of assets, any employee or director compensation, any compensation paid to employees or directors pursuant to stock appreciation rights, or obligations under operating leases For all purposes hereof, the Indebtedness of any Person shall, in the case of the Borrower and the Subsidiaries, exclude (i) all intercompany Indebtedness having a term not exceeding 364 days (inclusive of any roll over or extensions of terms) and made in the ordinary of business consistent with past practice in connection with the cash management activities of the Borrower and the Subsidiaries and (ii) customer deposits and advances and interest payable thereon in the ordinary course of business in accordance with customary trade terms and other obligations incurred in the ordinary course of business through credit on an open account basis customarily extended to such Person. The amount of any net obligation under any Hedging Agreement on any date shall be deemed to be the Agreement Value thereof as of such date. The amount of Indebtedness of any Person for purposes of clause (f) shall be deemed to be equal to the lesser of (i) the aggregate unpaid amount of such Indebtedness and (ii) the fair market value of the property encumbered thereby as determined by such Person in good faith.

Indemnified Taxes” shall mean (a) Taxes, other than Excluded Taxes, imposed on or with respect to any payment made by or on account of any obligation of any Loan Party under any Loan Document and (b) to the extent not otherwise described in (a), Other Taxes.

Indemnitee” shall have the meaning assigned to such term in Section 9.05(b).

Information” shall have the meaning assigned to such term in Section 9.16.

 

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Initial Borrowing” shall mean a borrowing comprised of Initial Loans of the same Type made, converted or continued on the same date and, in the case of Eurodollar Loans, as to which a single Interest Period is in effect.

Initial Commitment” shall mean, with respect to each Lender, the commitment of such Lender to make Initial Loans hereunder as set forth in Section 2.01(a). The initial amount of each Lender’s Initial Commitment is set forth on Schedule 2.01, or in the Assignment and Acceptance or Incremental Assumption Agreement pursuant to which such Lender shall have assumed its Initial Commitment, as applicable, as the same may be reduced or increased from time to time pursuant to assignments by or to such Lender pursuant to Section 9.04.

Initial Facility” shall mean (a) the Initial Tranche and (b) any tranche or series of Incremental Commitments under which Loans that are not Other Term Loans are made.

Initial Lender” shall mean a Lender with an Initial Commitment or an outstanding Initial Loan.

Initial Loan” shall mean a term loan made by an Initial Lender pursuant to Section 2.01(a).

Initial Reserve Report” shall mean the Reserve Report prepared by Cawley, Gillespie & Associates, Inc. as of June 1, 2014 with respect to the Oil and Gas Properties of the Borrower and the Subsidiary Guarantors (giving effect to the Acquisition).

Initial Tranche” shall mean the Initial Commitments and the Initial Loans made thereunder.

Interest Payment Date” shall mean (a) with respect to any ABR Loan, the last Business Day of each March, June, September and December, and (b) with respect to any Eurodollar Loan, the last day of the Interest Period applicable to the Borrowing of which such Loan is a part and, in the case of a Eurodollar Borrowing with an Interest Period of more than three months’ duration, each day that would have been an Interest Payment Date had successive Interest Periods of three months’ duration been applicable to such Borrowing.

Interest Period” shall mean, with respect to any Eurodollar Borrowing, the period commencing on the date of such Borrowing and ending on the numerically corresponding day (or, if there is no numerically corresponding day, on the last day) in the calendar month that is 1, 2, 3 or 6 months (or, if agreed to by all Lenders, 12 months) thereafter, as the Borrower may elect; provided, however, that (a) if any Interest Period would end on a day other than a Business Day, such Interest Period shall be extended to the next succeeding Business Day unless such next succeeding Business Day would fall in the next calendar month, in which case such Interest Period shall end on the next preceding Business Day, (b) any Interest Period that begins on the last Business Day of a calendar month (or on a day for which there is no numerically corresponding day in the calendar month at the end of such Interest Period) shall end on the last Business Day of the calendar month at the end of such Interest Period and (c) no Interest Period for any Loan shall extend beyond the Maturity Date or the Incremental Loan Maturity Date, as the case may be. Interest shall accrue from and including the first day of an Interest Period to but excluding the last day of such Interest Period. For purposes hereof, the date of a Borrowing initially shall be the date on which such Borrowing is made and thereafter shall be the effective date of the most recent conversion or continuation of such Borrowing.

 

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Internally Generated Cash” shall mean cash of the Borrower and the Consolidated Subsidiaries not constituting (x) proceeds of the issuance of (or contributions in respect of) Equity Interests, (y) proceeds of Dispositions outside of the ordinary course of business and Casualty Events or (z) proceeds of the incurrence of Indebtedness.

Investment” shall mean, for any Person: (a) the acquisition (whether for cash, property, services or securities or otherwise) of Equity Interests of any other Person (including, without limitation, any “short sale” or any sale of any securities at a time when such securities are not owned by the Person entering into such short sale); (b) the making of any advance, loan or capital contribution to, assumption of Indebtedness of, purchase or other acquisition of any other Indebtedness or equity participation or interest in, or other extension of credit to, any other Person (excluding (i) any such advance, loan or extension of credit representing the purchase price of inventory or supplies sold by such Person in the ordinary course of business and (ii) in the case of the Borrower and the Subsidiaries, intercompany loans, advances or Indebtedness having a term not exceeding 364 days (inclusive of any roll over or extensions of terms) and made in the ordinary of business consistent with past practice in connection with the cash management activities of the Borrower and the Subsidiaries); or (c) the entering into of any guarantee of, or other contingent obligation (including the deposit of any Equity Interests to be sold) with respect to, Indebtedness or other liability of any other Person and (without duplication) any amount committed to be advanced, lent or extended to such Person. For purposes of covenant compliance, the amount of any Investment shall be the amount actually invested, without adjustment for subsequent increases or decreases in the value of such Investment.

IRS” shall mean the United States Internal Revenue Service.

January 1 Reserve Report” shall have the meaning assigned to such term in Section 5.15(a).

July 1 Reserve Report” shall have the meaning assigned to such term in Section 5.15(a).

Lenders” shall mean (a) the Persons listed on Schedule 2.01 (other than any such Person that has ceased to be a party hereto pursuant to an Assignment and Acceptance) and (b) any Eligible Assignee that has become a party hereto pursuant to an Assignment and Acceptance or an Incremental Assumption Agreement.

Leverage Ratio” shall mean, on any Calculation Date, the ratio of Total Funded Debt on such Calculation Date to Consolidated EBITDAX for the period of four consecutive fiscal quarters most recently ended on or prior to such Calculation Date, in each case after giving effect to any applicable Pro Forma Adjustments.

LIBO Rate” shall mean, with respect to any Eurodollar Borrowing for any Interest Period, the rate per annum equal to the Intercontinental Exchange Benchmark Administration Ltd. LIBOR (“ICE LIBOR”), as published by Reuters (or other commercially available source providing quotations of ICE LIBOR as designated by the Administrative Agent from time to

 

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time) at approximately 11:00 a.m., London time, two Business Days prior to the commencement of such Interest Period, for deposits in Dollars (for delivery on the first day of such Interest Period) with a term equivalent to such Interest Period; provided that, to the extent that an interest rate is not ascertainable pursuant to the foregoing provisions of this definition, the “LIBO Rate” shall be the interest rate per annum determined by the Administrative Agent to be the average of the rates per annum at which deposits in Dollars are offered for such relevant Interest Period to major banks in the London interbank market in London, England by the Administrative Agent at approximately 11:00 a.m. (London time) on the date that is two Business Days prior to the beginning of such Interest Period.

Lien” shall mean, with respect to any asset, (a) any mortgage, deed of trust, lien, pledge, encumbrance, charge or security interest in or on such asset, (b) the interest of a vendor or a lessor under any conditional sale agreement, capital lease or title retention agreement (or any financing lease having substantially the same economic effect as any of the foregoing) relating to such asset, (c) in the case of securities, any purchase option, call or similar right of a third party with respect to such securities and (d) any lease burden on Oil and Gas Properties in the nature of a royalty, overriding royalty interest, net profits interest, production payment, carried interest or reversionary working interest.

Loan Documents” shall mean this Agreement, the Security Documents, any Incremental Assumption Agreement, and the promissory notes, if any, executed and delivered pursuant to Section 2.04(e) and any amendment, waiver or consent relating to the foregoing and any other document relating thereto that is by its terms designated as a “Loan Document”; provided that “Loan Documents” shall not include any Hedging Agreement or any Cash Management Agreement.

Loan Parties” shall mean Holdings, the Borrower and the Subsidiary Guarantors.

Loans” shall mean the Initial Loans and the Incremental Loans (if any).

Margin Stock” shall have the meaning assigned to such term in Regulation U.

Material Acquisition” shall mean an acquisition of assets equal in value to 25% or more of the PV-10 Value of the Borrower and the Subsidiary Guarantors set forth in the most recently delivered Reserve Report.

Material Adverse Effect” shall mean (a) a materially adverse effect on the business, assets, results of operations or financial condition of the Borrower and its Subsidiaries, taken as a whole, (b) a material adverse change in, or material impairment of, the ability of the Loan Parties (taken as a whole) to perform their obligations under the Loan Documents or (c) a material impairment of the rights and remedies of the Lenders under any Loan Document.

Material Contract” shall mean (a) each agreement or contract identified on Schedule 1.01(b), (b) each agreement or contract to which any Loan Party is a party or in respect of which any Loan Party has any liability, that by its terms (without reference to any indemnity or reimbursement provision therein) provides for aggregate future payments in respect of any such individual agreement or contract of at least $25,000,000 or (c) any other agreement or contract the loss of which would be reasonably likely to result in a Material Adverse Effect; provided

 

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that, (i) documents governing the lease or conveyance of Oil and Gas Properties (other than the Acquisition Agreement), (ii) other than for purposes of Sections 3.09(a) and 3.10(b), contracts related to field level or lease level operations with respect to the Oil and Gas Properties entered into in the ordinary course of business and (iii) the engagement letter dated as of June 17, 2014, among the Borrower and the Arrangers shall not be included in the definition of “Material Contract”.

Material Indebtedness” shall mean Indebtedness (other than the Loans), or obligations in respect of one or more Hedging Agreements, of any one or more of Holdings, the Borrower or any Subsidiary in an aggregate principal amount exceeding $25,000,000. For purposes of determining Material Indebtedness, the “principal amount” of the obligations of the Borrower or any Subsidiary in respect of any Hedging Agreement at any time shall be the Agreement Value of such Hedging Agreement at such time.

Maturity Date” shall mean January 22, 2019.

Maximum Rate” shall have the meaning assigned to such term in Section 9.09.

Moody’s” shall mean Moody’s Investors Service, Inc., or any successor thereto.

Mortgaged Properties” shall mean any property owned by the Borrower or any Subsidiary Guarantor which is subject to the Liens existing and to exist under the terms of the Mortgages.

Mortgages” shall mean the mortgages, deeds of trust, leasehold mortgages, assignments of production, modifications and other security documents delivered pursuant to clause (i) of Section 4.01(l) or pursuant to Section 5.13 or Section 5.14, each substantially in the form of Exhibit H.

Multiemployer Plan” shall mean a multiemployer plan as defined in Section 4001(a)(3) of ERISA.

Net Cash Proceeds” shall mean (a) with respect to any Asset Sale, the cash proceeds, net of (i) selling expenses (including reasonable broker’s fees or commissions, legal fees, transfer and similar taxes and the Borrower’s good faith estimate of income taxes paid or payable in connection with such sale), (ii) amounts provided as a reserve, in accordance with GAAP, against any liabilities under any indemnification obligations or purchase price adjustment associated with such Asset Sale (provided that, to the extent and at the time any such amounts are released from such reserve, such amounts shall constitute Net Cash Proceeds), (iii) the principal amount, premium or penalty, if any, interest and other amounts on any Indebtedness for borrowed money which is secured by the asset disposed of in such Asset Sale and which is required to be repaid with such proceeds (other than the Loans and any such Indebtedness assumed by the purchaser of such asset) and (iv) the Agreement Value due under any Hedging Agreement as a result of such Asset Sale that is paid by the Borrower or any Subsidiary; provided, however, that (x) no net cash proceeds calculated in accordance with the foregoing realized in a single transaction or series of related transactions shall constitute Net Cash Proceeds unless such net cash proceeds shall exceed $10,000,000 and (y) no such net cash proceeds shall constitute Net Cash Proceeds under this clause (a) in any fiscal year until the aggregate amount

 

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of all such net cash proceeds in such fiscal year shall exceed $20,000,000 (and thereafter only net cash proceeds in excess of such amount shall constitute Net Cash Proceeds under this clause (a)); and provided, further, that to the extent that (x) the Borrower shall deliver a certificate of a Financial Officer to the Administrative Agent at or prior to the time of receipt thereof setting forth the Borrower’s good faith intent to reinvest such proceeds in assets of a kind then used or usable in the business of the Borrower and its Subsidiaries within twelve months of receipt of such proceeds and (y) no Event of Default shall have occurred and shall be continuing at the time of such certificate or at the proposed time of the application of such proceeds, such proceeds shall not constitute Net Cash Proceeds except to the extent not so used at the end of such twelve-month period, at which time such proceeds shall be deemed to be Net Cash Proceeds; and (b) with respect to any issuance or incurrence of Indebtedness or any Equity Issuance, the cash proceeds thereof, net of all taxes and customary fees, commissions, costs and other expenses incurred in connection therewith.

Non-Consenting Lender” shall mean any Lender that does not approve any consent, waiver or amendment that (a) requires the approval of all affected Lenders in accordance with the terms of Section 9.08(b) and (b) has been approved by the Required Lenders.

Non-Defaulting Lender” shall mean, at any time, each Lender that is not a Defaulting Lender at such time.

Not Otherwise Applied” means, with reference to any amount of Net Cash Proceeds of any Equity Issuance, that such amount (i) was not previously applied in determining the permissibility of a transaction under the Loan Documents where such permissibility was contingent on receipt of such amount or utilization of such amount for a specified purpose and (ii) was not previously applied to effect a transaction or make a payment under any Loan Document.

Obligations” shall mean (a) the due and punctual payment by the Borrower of (i) the principal of and interest (including interest accruing during the pendency of any bankruptcy, insolvency, receivership or other similar proceeding, regardless of whether allowed or allowable in such proceeding) on the Loans, when and as due, whether at maturity, by acceleration, upon one or more dates set for prepayment or otherwise and (ii) all other monetary obligations of the Borrower under this Agreement and each of the other Loan Documents, including obligations to pay Applicable Premium, fees, expense reimbursement obligations (including with respect to attorneys’ fees) and indemnification obligations, whether primary, secondary, direct, contingent, fixed or otherwise (including monetary obligations incurred during the pendency of any bankruptcy, insolvency, receivership or other similar proceeding, regardless of whether allowed or allowable in such proceeding); provided that the indemnification obligations of the Borrower to any Indemnitee shall be secured and guaranteed pursuant to the Security Documents only to the extent that, and for so long as, the Loans owing to such Indemnitee’s related Lender are outstanding, (b) the due and punctual payment and performance of all the monetary obligations of each other Loan Party under or pursuant to each of the Loan Documents (including monetary obligations incurred during the pendency of any bankruptcy, insolvency, receivership or other similar proceeding, regardless of whether allowed or allowable in such proceeding) and (c) the due and punctual payment and performance of any and all monetary obligations of the Borrower and each Subsidiary (whether absolute or contingent and however and whenever created, arising,

 

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evidenced or acquired (including all renewals, extensions and modifications thereof and substitutions therefor)) arising under (A)(i) any Cash Management Agreement in respect of Cash Management Services or (ii) any Hedging Agreement, in each case that (x) are owed to the Administrative Agent, any Arranger or an Affiliate of any of the foregoing, or to any Person that, at the time such obligations were incurred, was the Administrative Agent, an Arranger or an Affiliate of any of the foregoing, (y) are owed on the Closing Date to a Person that is a Lender or an Affiliate of a Lender as of the Closing Date or (z) are owed to a Person that is a Lender or an Affiliate of a Lender at the time such obligations are incurred or (B) any Hedging Agreement with a Secured Non-Lender Hedge Provider; provided that (i) obligations of the Borrower or any Subsidiary under any such Cash Management Agreement shall be secured and guaranteed pursuant to the Security Documents only to the extent that, and for so long as, the Obligations other than in respect of such Cash Management Agreements and Hedging Agreements are so secured and guaranteed and (ii) any release of Collateral or Guarantors effected in the manner permitted by this Agreement shall not require the consent of holders of Obligations under Cash Management Agreements or Hedging Agreements. With respect to any Guarantor, if and to the extent, under the Commodity Exchange Act or any rule, regulation or order of the Commodity Futures Trading Commission (or the application or official interpretation of any thereof), all or a portion of the Guarantee of such Guarantor of, or the grant by such Guarantor of a security interest for, the obligation (the “Excluded Guarantor Obligation”) to pay or perform under any agreement, contract or transaction that constitutes a “swap” within the meaning of Section 1a(47) of the Commodity Exchange Act is or becomes illegal, the Obligations of such Guarantor shall not include any such Excluded Guarantor Obligation.

OFAC” shall have the meaning assigned to such term in Section 3.23.

Oil and Gas Properties” shall mean (a) Hydrocarbon Interests; (b) the properties now or hereafter pooled or unitized with Hydrocarbon Interests; (c) all presently existing or future unitization, pooling agreements and declarations of pooled units and the units created thereby (including, without limitation, all units created under orders, regulations and rules of any Governmental Authority) which may affect all or any portion of the Hydrocarbon Interests; (d) all operating agreements, contracts and other agreements, including production sharing contracts and agreements, which relate to any of the Hydrocarbon Interests or the production, sale, purchase, exchange or processing of Hydrocarbons from or attributable to such Hydrocarbon Interests; (e) all Hydrocarbons in and under and which may be produced and saved or attributable to the Hydrocarbon Interests, including all oil in tanks, and all rents, issues, profits, proceeds, products, revenues and other incomes from or attributable to the Hydrocarbon Interests; (f) all tenements, hereditaments, appurtenances and properties in any manner appertaining, belonging, affixed or incidental to the Hydrocarbon Interests; and (g) all properties, rights, titles, interests and estates described or referred to above, including any and all property, real or personal, now owned or hereinafter acquired and situated upon, used, held for use or useful in connection with the operating, working or development of any of such Hydrocarbon Interests or properties (excluding drilling rigs, automotive equipment, rental equipment or other personal property which may be on such premises for the purpose of drilling a well or for other similar temporary uses) and including any and all oil wells, gas wells, injection wells or other wells, buildings, structures, fuel separators, liquid extraction plants, plant compressors, pumps, pumping units, field gathering systems, tanks and tank batteries, fixtures, valves, fittings, machinery and parts, engines, boilers, meters, apparatus, equipment, appliances, tools,

 

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implements, cables, wires, towers, casing, tubing and rods, surface leases, rights-of-way, easements and servitudes together with all additions, substitutions, replacements, accessions and attachments to any and all of the foregoing.

Other Connection Taxes” shall mean, with respect to any Recipient, Taxes imposed as a result of a present or former connection between such Recipient and the jurisdiction imposing such Tax (other than connections arising from such Recipient having executed, delivered, become a party to, performed its obligations under, received payments under, received or perfected a security interest under, engaged in any other transaction pursuant to or enforced any Loan Document, or sold or assigned an interest in any Loan or Loan Document).

Other Taxes” shall mean all present or future stamp, court or documentary, intangible, recording, filing or similar Taxes that arise from any payment made under, from the execution, delivery, performance, enforcement or registration of, from the receipt or perfection of a security interest under, or otherwise with respect to, any Loan Document, except any such Taxes that are Other Connection Taxes imposed with respect to an assignment (other than an assignment made pursuant to Section 2.21).

Other Term Loans” shall have the meaning assigned to such term in Section 2.23(a).

Parent Entity” shall mean any direct or indirect parent of Holdings.

Participant” shall have the meaning assigned to such term in Section 9.04(f).

Participant Register” shall have the meaning assigned to such term in Section 9.04(f).

PDP Reserves” shall mean those Oil and Gas Properties designated as “proved developed and producing” (in accordance with SEC definitions and regulations) in the Reserve Report most recently delivered to the Administrative Agent pursuant to this Agreement.

Permitted Acquisition” shall mean any transaction or series of related transactions effected by the Borrower or a Subsidiary Guarantor (or a Person that will become a Subsidiary Guarantor substantially concurrently with such transaction or series of related transactions) for the direct or indirect (a) acquisition of Oil and Gas Properties; (b) acquisition of in excess of 50% of the Equity Interests of any Person, and otherwise causing such Person to become a Subsidiary of the Borrower or a Subsidiary Guarantor; or (c) merger, amalgamation or consolidation or any other combination with any Person, if each of the following conditions is met:

(i) no Event of Default then exists or would result therefrom;

(ii) neither the Borrower nor any Subsidiary shall, in connection with any such transaction, assume or remain liable with respect to any Indebtedness except to the extent permitted under Section 6.01;

(iii) (A) with respect to an acquisition of assets, the assets so acquired shall be made subject to the Lien of the Security Documents to the extent required by Section 5.14 and (B) with respect to the acquisition of more than 50% of the Equity Interests in a

 

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Person, the Person or business to be acquired shall be, or shall be engaged in, a business of the type that the Loan Parties and their Subsidiaries are permitted to be engaged in under Section 6.09 and such Person shall become a Subsidiary Guarantor and the property acquired in connection with any such transaction shall be made subject to the Lien of the Security Documents to the extent required by Section 5.14;

(iv) all transactions in connection therewith shall be consummated in accordance with all applicable laws of all applicable Governmental Authorities;

(v) with respect to any Material Acquisition, unless the Administrative Agent shall otherwise agree, the Borrower shall have provided the Administrative Agent with (A) in the case of an acquisition of a Person, historical financial statements for the last two fiscal years (or, if less, the number of years since formation) of the Person to be acquired and interim unaudited financial statements for the most recent interim period which is available or, in the case of an acquisition of Oil and Gas Properties, operating statements for the last two fiscal years prepared by the seller with respect to the Proved Reserves acquired and, to the extent available, interim operating statements for any completed fiscal quarters, and (B) a reserve report setting forth all information required to be contained in a “Reserve Report” as defined herein, or an excerpt therefrom containing all such information, with respect to the Proved Reserves to be acquired pursuant to such acquisition (provided that such report may be prepared by independent reserve engineers other than the Approved Petroleum Engineer) with an effective date within the 12-month period immediately prior to such acquisition, and (C) reasonably detailed projections for the succeeding five years pertaining to the Person, business or assets to be acquired and updated projections for the Borrower after giving effect to such transaction, and (D) a reasonably detailed description of all material information relating thereto and copies of all material documentation pertaining to such transaction; and

(vi) with respect to any Material Acquisition, at least three (3) Business Days prior to the proposed date of consummation of the transaction, the Borrower shall have delivered to the Administrative Agent an officers’ certificate certifying that such transaction complies with this definition.

Permitted Cure Security” shall mean any Qualified Capital Stock of the Borrower.

Permitted Investments” shall mean:

(a) direct obligations of, or obligations the principal of and interest on which are unconditionally guaranteed by, the United States of America (or by any agency thereof to the extent such obligations are backed by the full faith and credit of the United States of America), in each case maturing within one year from the date of issuance thereof;

(b) investments in commercial paper maturing within one year from the date of issuance thereof and having, at such date of acquisition, a rating of at least A-2 or P-2 from S&P or from Moody’s, respectively;

 

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(c) investments in certificates of deposit, banker’s acceptances and time deposits maturing within one year from the date of acquisition thereof issued or guaranteed by or placed with, and money market deposit accounts issued or offered by, the Administrative Agent or any domestic office of any commercial bank organized under the laws of the United States of America or any State thereof that has a combined capital and surplus and undivided profits of not less than $250,000,000 and that issues (or the parent of which issues) commercial paper rated at least “Prime-1” (or the then equivalent grade) by Moody’s or “A-1” (or the then equivalent grade) by S&P;

(d) fully collateralized repurchase agreements for securities described in clause (a) above and entered into with a financial institution satisfying the criteria of clause (c) above;

(e) securities with average maturities of 12 months or less from the date of acquisition issued or fully guaranteed by any state, commonwealth or territory of the United States, by any political subdivision or taxing authority of any such state, commonwealth or territory or by any foreign government having an investment grade rating from either S&P or Moody’s (or the equivalent thereof);

(f) investments with average maturities of 12 months or less from the date of acquisition in money market funds rated AAA- (or the equivalent thereof) or better by S&P or Aaa3 (or the equivalent thereof) or better by Moody’s; and

(g) investments in “money market funds” within the meaning of Rule 2a-7 of the Investment Company Act of 1940, as amended, substantially all of whose assets are invested in investments of the type described in clauses (a) through (f) above.

Permitted Investors” shall mean, collectively, each officer or other members of management of Holdings that hold Equity Interests in Holdings as of the Closing Date, Hunt Pettit and Brian Nelson and any of their respective family members, descendants, heirs, family trusts or other similar entities or similar arrangements, and any trustee under any such family trusts or other similar arrangement.

Permitted Refinancing Indebtedness” means, with respect to any Person, any modification, refinancing, refunding, renewal, replacement or extension of any Indebtedness of such Person; provided that (a) the principal amount (or accreted value, if applicable) thereof does not exceed the principal amount (or accreted value, if applicable) of the Indebtedness so modified, refinanced, refunded, renewed, replaced or extended except by an amount equal to accrued and unpaid interest and any applicable premium thereon plus other reasonable amounts paid, and fees and expenses reasonably incurred, in connection with such modification, refinancing, refunding, renewal, replacement or extension and by an amount equal to any existing commitments unutilized thereunder; (b) other than with respect to Permitted Refinancing Indebtedness in respect of Indebtedness permitted under Section 6.01(e), such modification, refinancing, refunding, renewal, replacement or extension has a final maturity date equal to or later than the earlier of (x) the final maturity date of the Indebtedness being modified, refinanced, refunded, renewed, replaced or extended and (y) the date which is 91 days after the Maturity Date; (c) other than with respect to Permitted Refinancing Indebtedness in respect of

 

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Indebtedness permitted pursuant to Section 6.01(e), such modification, refinancing, refunding, renewal or extension has a weighted average life to maturity equal to or greater than the remaining weighted average life to maturity of the Indebtedness being modified, refinanced, refunded, renewed, replaced or extended; (d) if the Indebtedness being modified, refinanced, refunded, renewed, replaced, exchanged or extended is subordinated in right of payment to the Obligations, such modification, refinancing, refunding, renewal, replacement or extension is subordinated in right of payment to the Obligations on terms, taken as a whole, as favorable in all material respects to the Lenders as those contained in the documentation governing the Indebtedness being modified, refinanced, refunded, renewed, replaced or extended; (d) if the Indebtedness being modified, refinanced, refunded, renewed, replaced or extended is secured by a junior-priority security interest in the Collateral and/or subject to any intercreditor arrangements for the benefit of the Lenders, such modification, refinancing, refunding, renewal, replacement or extension is secured and subject to intercreditor arrangements on terms, taken as a whole, as favorable in all material respects to the Lenders as those contained in the documentation governing the Indebtedness being modified, refinanced, refunded, renewed, replaced or extended; and (e) the terms and conditions (including, if applicable, as to collateral, but excluding as to interest rate or other pricing terms and redemption or prepayment premiums) of any such modified, refinanced, refunded, renewed, replaced or extended Indebtedness are not materially less favorable to the Lenders, taken as a whole, than the terms and conditions of the Indebtedness being modified, refinanced, refunded, renewed, replaced, exchanged or extended.

Person” shall mean any natural person, corporation, business trust, joint venture, association, company, limited liability company, partnership, Governmental Authority or other entity.

Petro Capital Letter Agreement” means, collectively, the Letter Agreement dated June 7, 2012 and the Letter Agreement dated June 26, 2012, in each case, among Petro Capital XXV, LLC, Energy & Exploration Partners, LLC, a Delaware limited liability company, Energy & Exploration Partners, LP, a Delaware limited partnership, and North American Shale Investment Fund, LP, a Delaware limited partnership as in effect on the Closing Date.

Petro Capital Overrides” means any and all overriding royalty interests granted to the Petro Entities, or any of them, pursuant to the “Note” and/or the “Note Purchase Agreement” (as each such term is defined in the Petro Capital Letter Agreement), in each case, as in effect on the Closing Date; provided that any “Exchange Rights” (as defined in the Petro Capital Letter Agreement) and any overriding royalty interests granted upon the valid exercise thereof shall be deemed to constitute “Petro Capital Overrides”.

Petro Entities” means, collectively, (a) Petro Capital XXV, LLC, a Texas limited liability company, (b) PetroStone, LLC, a Texas limited liability company, (c) Province Energy, LLC, a Texas limited liability company, (d) 4600 Greenville Building, LP, a Texas limited partnership, (e) Pitts Oil, LLC, a Texas limited liability company, and (f) the successors and assigns of each of the foregoing entities.

Plan” shall mean any employee pension benefit plan (other than a Multiemployer Plan) subject to the provisions of Title IV of ERISA or Section 412 of the Code or Section 302 of ERISA, and in respect of which the Borrower or any ERISA Affiliate is (or, if such plan were terminated, would under Section 4069 of ERISA be deemed to be) an “employer” as defined in Section 3(5) of ERISA.

 

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Platform” shall have the meaning assigned to such term in Section 9.01.

Prime Rate” shall mean the rate of interest per annum determined from time to time by Credit Suisse as its prime rate in effect at its principal office in New York City and notified to the Borrower. The prime rate is a rate set by Credit Suisse based upon various factors including Credit Suisse’s costs and desired return, general economic conditions and other factors, and is used as a reference point for pricing some loans, which may be priced at, above, or below such rate.

Pro Forma Adjustments” shall mean, for purposes of calculating compliance with any financial covenant or financial term as of any Calculation Date:

(a) acquisitions that have been made by the Borrower or any of its Subsidiaries, including through mergers or consolidations, or any Person or any of its subsidiaries acquired by the Borrower or any of its Subsidiaries, and including all related financing transactions and including increases in ownership of Subsidiaries, non-recurring or one-time cash or non-cash charges or expenses associated with such acquisition, and other pro form adjustments (calculated in accordance with Regulation S-X under the Securities Exchange Act of 1934, as amended) during the four-quarter reference period or subsequent to such reference period and on or prior to the Calculation Date, or that are to be made on the Calculation Date, will be given pro forma effect as if they had occurred on the first day of the four-quarter reference period;

(b) the Consolidated EBITDAX attributable to discontinued operations, as determined in accordance with GAAP, and operations or businesses (and ownership interests therein) disposed of during the four-quarter reference period or subsequent to such reference period and on or prior to the Calculation Date, will be excluded; and

(c) if any Indebtedness bears a floating rate of interest, the interest expense on such Indebtedness will be calculated as if the rate in effect on the Calculation Date had been the applicable rate for the entire four-quarter reference period and subsequent period through the Calculation Date (taking into account any Hedging Agreement applicable to such Indebtedness if such Hedging Agreement has a remaining term as at the Calculation Date in excess of 12 months).

Proved Reserves” shall mean those Oil and Gas Properties designated as “proved” (in accordance with SEC definitions and regulations) in the Reserve Report most recently delivered to the Administrative Agent pursuant to this Agreement.

Proved Reserves Coverage Ratio” shall mean, (a) the ratio of the PV-10 Value of the Borrower’s and the Subsidiary Guarantors’ Proved Reserves as reflected in the most recent January 1 Reserve Report (together with any supplements, revisions or updates thereto after such date) to Total Funded Debt as shown in the annual financial statements for the immediately prior fiscal year and (b) the ratio of the PV-10 Value of the Borrower’s and the Subsidiary Guarantors’ Proved Reserves as reflected in the most recent July 1 Reserve Report (together with any supplements, revisions or updates thereto after such date) to Total Funded Debt as shown in the quarterly financial statements for the quarter ending June 30 of the current fiscal year.

 

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Public Lender” shall have the meaning assigned to such term in Section 9.01.

PV-10 Value” shall mean, as of any date of determination for the Borrower and the Subsidiary Guarantors, the discounted net present value, on a pre-income tax basis, of projected future cash flows from the production of Proved Reserves attributable to the Borrower’s and the Subsidiary Guarantors’ Oil and Gas Properties as set forth in the most recent Reserve Report delivered pursuant hereto, calculated in accordance with the SEC guidelines and using the five-year strip price for crude oil (WTI Cushing or Light Louisiana Sweet) and natural gas (Henry Hub), with such price held flat for each subsequent year, quoted on the New York Mercantile Exchange (or its successor) on such date of determination and adjusted by appropriate management adjustments for additions to reserves and depletion or sale of reserves since the date of such Reserve Report, adjusted for any basis differential as of the date of determination, as of the date of estimation without future escalation, and discounted using an annual discount rate of 10%. PV-10 Value shall be adjusted to give effect to the Hedging Agreements permitted by this Agreement then in effect.

Qualified Capital Stock” of any Person shall mean any Equity Interest of such Person that is not Disqualified Stock.

Qualified IPO” means the issuance by Holdings of its common Equity Interests in an underwritten primary public offering (other than a public offering pursuant to a registration statement on Form S-8) pursuant to an effective registration statement filed with the U.S. Securities and Exchange Commission in accordance with the Securities Act of 1933.

Recipient” shall mean (a) the Administrative Agent and (b) any Lender, as applicable.

Register” shall have the meaning assigned to such term in Section 9.04(d).

Regulation T” shall mean Regulation T of the Board as from time to time in effect and all official rulings and interpretations thereunder or thereof.

Regulation U” shall mean Regulation U of the Board as from time to time in effect and all official rulings and interpretations thereunder or thereof.

Regulation X” shall mean Regulation X of the Board as from time to time in effect and all official rulings and interpretations thereunder or thereof.

Related Fund” shall mean, with respect to any Lender that is a fund or commingled investment vehicle that invests in bank loans, any other fund that invests in bank loans and is managed or advised by the same investment advisor as such Lender or by an Affiliate of such investment advisor.

Related Parties” shall mean, with respect to any specified Person, such Person’s Affiliates and the respective partners, directors, trustees, officers, employees, attorneys, agents, administrators, managers, advisors and representatives of such Person and such Person’s Affiliates.

 

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Release” shall mean any release, spill, emission, leaking, dumping, injection, pouring, deposit, disposal, discharge, dispersal, leaching or migration into or through the environment or from, within or upon any vessel, vehicle, equipment, building, structure, facility or fixture.

Remedial Work” shall have the meaning assigned to such term in Section 5.12(a).

Repayment Date” shall have the meaning given such term in Section 2.11(a).

Required Lenders” shall mean, at any time, Lenders having Loans representing more than 50% of the sum of all Loans outstanding at such time; provided that the Loans of any Defaulting Lender shall be disregarded in the determination of the Required Lenders at any time.

Reserve Report” shall mean, the Initial Reserve Report or the most recently delivered report delivered pursuant to Section 5.15, each of which report shall, as of its date, set forth the oil and gas reserves attributable to the Oil and Gas Properties of the Borrower and the Subsidiary Guarantors and each of which report shall be in form and substance reasonably satisfactory to the Administrative Agent, and shall, at a minimum, set forth each such Loan Party’s royalty interests, oil and gas reserves (including proved developed producing, proved developed non-producing, proved undeveloped and probable reserves) and a projection of the rate of production and future net income, taxes, operating expenses and capital expenditures with respect thereto as of such date.

Responsible Officer” of any Person shall mean any President, Vice President, executive officer or Financial Officer of such Person and any other officer or similar official thereof responsible for the administration of the obligations of such Person in respect of this Agreement.

Restricted Indebtedness” shall mean Indebtedness of the Borrower or any Subsidiary, the payment, prepayment, repurchase or defeasance of which is restricted under Section 6.10(d).

Restricted Payment” shall mean any dividend or other distribution (whether in cash, securities or other property) with respect to any Equity Interests in the Borrower or any Subsidiary, or any payment (whether in cash, securities or other property), including any sinking fund or similar deposit, on account of the purchase, redemption, retirement, acquisition, cancellation or termination of any Equity Interests in the Borrower or any Subsidiary or any option, warrant or other right to acquire any such Equity Interests in the Borrower or any of its Subsidiaries.

S&P” shall mean Standard & Poor’s Ratings Service, or any successor thereto.

SEC” shall mean the Securities and Exchange Commission.

Secured Non-Lender Hedge Provider” shall have the meaning assigned to such term in the definition of “Secured Parties”.

 

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Secured Parties” means (a) the Administrative Agent, (b) the Collateral Agent, (c) the Lenders, (d) any Approved Counterparty that is a counterparty to any Hedging Agreement with any Loan Party; provided that such Approved Counterparty is (i) an Agent, an Arranger, a Lender, an Affiliate of an Agent, an Affiliate of an Arranger, or an Affiliate of a Lender at the time such Hedging Agreement is entered into or (ii) designated as a “Secured Non-Lender Hedge Provider” with respect to such Hedging Agreement in a writing from the Borrower to the Administrative Agent and, in the case of clauses (i) and (ii), with respect to any Approved Counterparty that is not a Lender, delivers to the Administrative Agent a letter agreement reasonably satisfactory to the Administrative Agent (A) appointing the Collateral Agent as its agent under the applicable Loan Documents and (B) agreeing to be bound by Articles VII and VIII and Sections 9.05, 9.06, 9.07, 9.11, 9.17, 9.19 and 9.20 of this Agreement as if it were a Lender hereunder (such Approved Counterparty, a “Secured Non-Lender Hedge Provider”), (e) any Agent, an Arranger, a Lender, an Affiliate of an Agent, an Affiliate of an Arranger, or an Affiliate of a Lender that provides Cash Management Services to any Loan Party pursuant to a Cash Management Agreement and (f) the beneficiaries of the indemnification obligations undertaken by any Loan Party under any Loan Document.

Security Documents” shall mean the Mortgages, the Guarantee and Collateral Agreement and each of the security agreements, mortgages and other instruments and documents executed and delivered pursuant to any of the foregoing or pursuant to Sections 5.13 or 5.14 or any Incremental Assumption Agreement.

SPV” shall have the meaning assigned to such term in Section 9.04(i).

SPV Register” shall have the meaning specified in Section 9.04(i).

Statutory Reserves” shall mean a fraction (expressed as a decimal), the numerator of which is the number one and the denominator of which is the number one minus the aggregate of the maximum reserve percentages (including any marginal, special, emergency or supplemental reserves) expressed as a decimal established by the Board and any other banking authority, domestic or foreign, to which the Administrative Agent or any Lender (including any branch, Affiliate or other fronting office making or holding a Loan) is subject for Eurocurrency Liabilities (as defined in Regulation D of the Board). Eurodollar Loans shall be deemed to constitute Eurocurrency Liabilities (as defined in Regulation D of the Board) and to be subject to such reserve requirements without benefit of or credit for proration, exemptions or offsets that may be available from time to time to any Lender under such Regulation D. Statutory Reserves shall be adjusted automatically on and as of the effective date of any change in any reserve percentage.

subsidiary” shall mean, with respect to any Person (herein referred to as the “parent”), any corporation, partnership, limited liability company, association or other business entity (a) of which securities or other ownership interests representing more than 50% of the equity or more than 50% of the ordinary voting power or more than 50% of the general partnership interests are, at the time any determination is being made, owned, Controlled or held, or (b) that is, at the time any determination is made, otherwise Controlled, by the parent or one or more subsidiaries of the parent or by the parent and one or more subsidiaries of the parent.

 

33


Subsidiary” shall mean any subsidiary of Borrower.

Subsidiary Guarantor” shall mean, each Subsidiary listed on Schedule 1.01(a), and each other Subsidiary that is or becomes a party to the Guarantee and Collateral Agreement pursuant to Sections 5.13 or 5.14.

Synthetic Lease” shall mean, as to any Person, any lease (including leases that may be terminated by the lessee at any time) of any property (whether real, personal or mixed) (a) that is accounted for as an operating lease under GAAP and (b) in respect of which the lessee retains or obtains ownership of the property so leased for income tax purposes, other than any such lease under which such Person is the lessor.

Synthetic Lease Obligations” shall mean, as to any Person, an amount equal to the capitalized amount of the remaining lease payments under any Synthetic Lease that would appear on a balance sheet of such person in accordance with GAAP if such obligations were accounted for as Capital Lease Obligations.

Synthetic Purchase Agreement” shall mean any swap, derivative or other agreement or combination of agreements pursuant to which the Borrower or any Subsidiary is or may become obligated to make (a) any payment in connection with a purchase by any third party from a Person other than the Borrower or any Subsidiary of any Equity Interest or Restricted Indebtedness or (b) any payment (other than on account of a permitted purchase by it of any Equity Interest or Restricted Indebtedness) the amount of which is determined by reference to the price or value at any time of any Equity Interest or Restricted Indebtedness; provided that no phantom stock or similar plan providing for payments only to current or former directors, officers or employees of the Borrower or the Subsidiaries (or to their heirs or estates) shall be deemed to be a Synthetic Purchase Agreement.

Taxes” shall mean all present or future taxes, levies, imposts, duties, deductions, withholdings (including backup withholding), assessments, fees or other charges imposed by any Governmental Authority, including any interest, additions to tax or penalties applicable thereto.

Total Funded Debt” shall mean, on any date, (i) all Indebtedness of the Borrower and the Consolidated Subsidiaries of the type described in clauses (a), (b) (to the extent of obligations thereunder not reimbursed within two Business Days), (e), (l) and (m) of the definition of “Indebtedness” on such date, less (ii) all unrestricted cash and Permitted Investments of the Borrower and the Consolidated Subsidiaries on such date.

Transaction Costs” shall have the meaning assigned to such term in the recitals hereto.

Transactions” shall mean, collectively, (a) the execution, delivery and performance by the Loan Parties of the Loan Documents to which they are a party and the making of the Borrowings hereunder, in each case, on the Closing Date, (b) the consummation of the Acquisition, (c) the refinancing and replacement of the Existing Debt, (d) the issuance of the Holdings Notes and the contribution by Holdings of the Net Cash Proceeds thereof to the Borrower, (e) the payment of the Transaction Costs, and (f) any other transaction related to or entered into in connection with any of the foregoing.

 

34


Type”, when used in respect of any Loan or Borrowing, shall refer to the Rate by reference to which interest on such Loan or on the Loans comprising such Borrowing is determined. For purposes hereof, the term “Rate” shall mean the Adjusted LIBO Rate and the Alternate Base Rate.

U.S. Person” shall mean a “United States person” within the meaning of Section 7701(a)(30) of the Code.

U.S. Tax Compliance Certificate” shall have the meaning assigned to such term in Section 2.20(e)(ii)(B)(3).

USA PATRIOT Act” shall mean The Uniting and Strengthening America by Providing Appropriate Tools Required to Intercept and Obstruct Terrorism Act of 2001 (Title III of Pub. L. No. 107-56 (signed into law October 26, 2001)).

Voting Stock” shall mean, with respect to any specified Person, the Equity Interests of such Person entitling the holders thereof (whether at all times or only so long as no senior class of Equity Interest has voting power by reason of any contingency) to vote in the election of members of the board of directors, board of managers or similar governing body of such Person; provided that with respect to a limited partnership or other entity which does not have a board of directors (or similar governing body), Voting Stock means the Equity Interests of the general partner of such limited partnership or other business entity with the ultimate authority to manage the business and operations of such Person.

Withdrawal Liability” shall mean liability to a Multiemployer Plan as a result of a complete or partial withdrawal from such Multiemployer Plan, as such terms are defined in Part I of Subtitle E of Title IV of ERISA.

Withholding Agent” shall mean any Loan Party and the Administrative Agent.

Yield” shall mean, on any date on which the “Yield” is required to be calculated pursuant to Section 2.23(b), the internal rate of return on the Loans on the Closing Date (or as thereafter amended) and/or Other Term Loans, as applicable, determined by the Administrative Agent in consultation with the Borrower utilizing (a) any “LIBOR floor” applicable to the Loans and/or Other Term Loans on such date; (b) the Applicable Margin (or equivalent concept) for the Loans and/or Other Term Loans, as applicable, on such date; and (c) the issue price of the Loans and/or Other Term Loans, as applicable (after giving effect to any original issue discount or upfront fees paid to the market (but excluding commitment or arrangement fees in respect of the Loans and such Other Term Loans, as applicable) in respect of the Loans and/or Other Term Loans, as applicable, calculated based on an assumed four year average life to maturity).

B. Terms Generally. The definitions in Section 1.01 shall apply equally to both the singular and plural forms of the terms defined. Whenever the context may require, any pronoun shall include the corresponding masculine, feminine and neuter forms. The words “include”, “includes” and “including” shall be deemed to be followed by the phrase “without limitation”. The word “will” shall be construed to have the same meaning and effect as the word “shall”. Unless the context requires otherwise (i) any definition of or reference to any agreement, instrument or other document herein shall be construed as referring to such agreement,

 

35


instrument or other document as from time to time amended, supplemented or otherwise modified (subject to any restrictions on such amendments, supplements or modifications set forth herein), (ii) any reference herein to any Person shall be construed to include such Person’s successors and permitted assigns, (iii) the words “herein,” “hereof” and “hereunder,” and words of similar import, shall be construed to refer to this Agreement in its entirety and not to any particular provision hereof, (iv) any reference to any law or regulation herein shall, unless otherwise specified, refer to such law or regulation as amended, modified or supplemented from time to time, and (v) the words “asset” and “property” shall be construed as having the same meaning and effect and to refer to any and all tangible and intangible assets and properties, including cash, securities, accounts and contract rights. All references herein to Articles, Sections, Exhibits and Schedules shall be deemed references to Articles and Sections of, and Exhibits and Schedules to, this Agreement unless the context shall otherwise require. Except as otherwise expressly provided herein, all terms of an accounting or financial nature shall be construed in accordance with GAAP; provided, however that, notwithstanding anything to the contrary herein, all accounting or financial terms used herein shall be construed, and all financial computations pursuant hereto shall be made, without giving effect to any election under ASC 825 to value any Indebtedness or other liabilities of any Loan Party at “fair value”, as defined therein.

C. Pro Forma Calculations . All pro forma calculations permitted or required to be made by the Borrower or any Subsidiary pursuant to this Agreement shall include only those adjustments that have been certified by a Financial Officer of the Borrower as having been prepared in good faith based upon assumptions that were believed to be reasonable at the time of preparation and, where required, calculated in accordance with Regulation S-X under the Securities Act of 1934, as amended.

D. Classification of Loans and Borrowings. For purposes of this Agreement, Loans may be classified by Type (e.g., a “Eurodollar Loan”). Borrowings also may be classified and referred to by Type (e.g., a “Eurodollar Borrowing”).

2.

The Credits

A. Commitments. Subject to the terms and conditions and relying upon the representations and warranties herein set forth, (a) each Lender agrees, severally and not jointly, to make an Initial Loan to the Borrower on the Closing Date in a principal amount not to exceed its Initial Commitment, and (b) each Lender having an Incremental Commitment agrees, severally and not jointly, subject to the terms and conditions set forth in the applicable Incremental Assumption Agreement, to make an Incremental Loan to the Borrower on the applicable Increased Amount Date in a principal amount not to exceed its Incremental Commitment. Amounts paid or prepaid in respect of Loans may not be reborrowed.

B. Loans. i. Each Loan shall be made as part of a Borrowing consisting of Loans made by the Lenders ratably in accordance with their applicable Commitments; provided, however, that the failure of any Lender to make any Loan shall not in itself relieve any other Lender of its obligation to lend hereunder (it being understood, however, that no Lender shall be responsible for the failure of any other Lender to make any Loan required to be made by such

 

36


other Lender). The Loans comprising any Borrowing shall be in an aggregate principal amount that is (i) an integral multiple of $1,000,000 and not less than $5,000,000 or (ii) equal to the remaining available balance of the applicable Commitment.

ii. Subject to Sections 2.08 and 2.15, each Borrowing shall be comprised entirely of ABR Loans or Eurodollar Loans as the Borrower may request pursuant to Section 2.03. Each Lender may at its option make any Eurodollar Loan by causing any domestic or foreign branch or Affiliate of such Lender to make such Loan; provided that any exercise of such option shall not affect the obligation of the Borrower to repay such Loan in accordance with the terms of this Agreement. Borrowings of more than one Type may be outstanding at the same time; provided, however, that the Borrower shall not be entitled to request any Borrowing that, if made, would result in more than ten Eurodollar Borrowings outstanding hereunder at any time. For purposes of the foregoing, Borrowings having different Interest Periods, regardless of whether they commence on the same date, shall be considered separate Borrowings.

iii. Each Lender shall make each Loan to be made by it hereunder on the proposed date thereof by wire transfer of immediately available funds to such account in New York City as the Administrative Agent may designate not later than 1:00 p.m., New York City time, and the Administrative Agent shall promptly credit the amounts so received to an account designated by the Borrower in the applicable Borrowing Request or, if a Borrowing shall not occur on such date because any condition precedent herein specified shall not have been met, return the amounts so received to the respective Lenders.

iv. Notwithstanding anything to the contrary contained herein (and without affecting any other provisions hereof), the funded portion of each Loan to be made on the Closing Date (i.e., the amount advanced to the Borrower on the Closing Date) shall be equal to 98.5% of the principal amount of such Loan (it being agreed that the full principal amount of each such Loan shall be the “initial” principal amount of such Loan and deemed outstanding on the Closing Date and the Borrower shall be obligated to repay 100% of the principal amount of each such Loan as provided hereunder).

C. Borrowing Procedure. In order to request a Borrowing, the Borrower shall notify the Administrative Agent of such request by telephone (a) in the case of a Eurodollar Borrowing, not later than 12:00 (noon), New York City time, three Business Days before a proposed Borrowing, and (b) in the case of an ABR Borrowing, not later than 12:00 (noon), New York City time, on the day of the proposed Borrowing. Each such telephonic Borrowing Request shall be irrevocable, and shall be confirmed promptly by hand delivery or fax to the Administrative Agent of a written Borrowing Request and shall specify the following information: (i) whether such Borrowing is to be a Eurodollar Borrowing or an ABR Borrowing (provided that, until the Administrative Agent shall have notified the Borrower that the primary syndication of the Commitments has been completed (which notice shall be given as promptly as practicable and, in any event, within 30 days after the Closing Date), the Borrower shall not be permitted to request a Eurodollar Borrowing with an Interest Period in excess of one month); (ii) the date of such Borrowing (which shall be a Business Day); (iii) the number and location of the account to which funds are to be disbursed; (iv) the amount of such Borrowing; (v) if such Borrowing is to be a Eurodollar Borrowing, the Interest Period with respect thereto; and (vi) whether such Borrowing is to be a Borrowing of Initial Loans or Incremental Loans (and, in the

 

37


case of Incremental Loans, whether such Loans are to be Other Term Loans); provided, however, that, notwithstanding any contrary specification in any Borrowing Request, each requested Borrowing shall comply with the requirements set forth in Section 2.02. If no election as to the Type of Borrowing is specified in any such notice, then the requested Borrowing shall be an ABR Borrowing. If no Interest Period with respect to any Eurodollar Borrowing is specified in any such notice, then the Borrower shall be deemed to have selected an Interest Period of one month’s duration. The Administrative Agent shall promptly advise the applicable Lenders of any notice given pursuant to this Section 2.03 (and the contents thereof), and of each Lender’s portion of the requested Borrowing.

D. Evidence of Debt; Repayment of Loans. i. The Borrower hereby unconditionally promises to pay to the Administrative Agent for the account of each Lender the principal amount of each Loan of such Lender as provided in Section 2.11.

ii. Each Lender shall maintain in accordance with its usual practice an account or accounts evidencing the indebtedness of the Borrower to such Lender resulting from each Loan made by such Lender from time to time, including the amounts of principal and interest payable and paid to such Lender from time to time under this Agreement.

iii. The Administrative Agent shall maintain accounts in which it will record (i) the amount of each Loan made hereunder, the Type thereof and, if applicable, the Interest Period applicable thereto, (ii) the amount of any principal or interest due and payable or to become due and payable from the Borrower to each Lender hereunder and (iii) the amount of any sum received by the Administrative Agent hereunder from the Borrower or any Guarantor and each Lender’s share thereof.

iv. The entries made in the accounts maintained pursuant to paragraphs (b) and (c) above shall be prima facie evidence of the existence and amounts of the obligations therein recorded (absent manifest error); provided, however, that the failure of any Lender or the Administrative Agent to maintain such accounts or any error therein shall not in any manner affect the obligations of the Borrower to repay the Loans in accordance with their terms.

v. Any Lender may request that Loans made by it hereunder be evidenced by a promissory note. In such event, the Borrower shall execute and deliver to such Lender a promissory note payable to such Lender and its registered assigns and in a form and substance reasonably acceptable to the Administrative Agent and the Borrower. Notwithstanding any other provision of this Agreement, in the event any Lender shall request and receive such a promissory note, the interests represented by such note shall at all times (including after any assignment of all or part of such interests pursuant to Section 9.04) be represented by one or more promissory notes payable to the payee named therein or its registered assigns.

E. Fees. The Borrower agrees to pay to the Administrative Agent, for its own account, the administrative fees as separately agreed in a writing between the Borrower and the Administrative Agent at the times and in the amounts specified therein (the “Administrative Agent Fees”).

 

38


F. Interest on Loans. i. Subject to the provisions of Section 2.07, the Loans comprising each ABR Borrowing shall bear interest (computed on the basis of the actual number of days elapsed over a year of 365 or 366 days, as the case may be, and calculated from and including the date of such Borrowing to but excluding the date of repayment thereof) at a rate per annum equal to the Alternate Base Rate plus the Applicable Margin.

ii. Subject to the provisions of Section 2.07, the Loans comprising each Eurodollar Borrowing shall bear interest (computed on the basis of the actual number of days elapsed over a year of 360 days and calculated from and including the date of such Borrowing to but excluding the date of repayment thereof) at a rate per annum equal to the Adjusted LIBO Rate for the Interest Period in effect for such Borrowing plus the Applicable Margin.

iii. Interest on each Loan shall be payable on the Interest Payment Dates applicable to such Loan except as otherwise provided in this Agreement. The applicable Alternate Base Rate or Adjusted LIBO Rate for each Interest Period or day within an Interest Period, as the case may be, shall be determined by the Administrative Agent, and such determination shall be conclusive absent manifest error.

G. Default Interest. If the Borrower shall default in the payment of any principal of or interest on any Loan or any other amount due hereunder or under any other Loan Document, by acceleration or otherwise, then until such defaulted amount shall have been paid in full, to the extent permitted by law, such overdue amount shall bear interest (after as well as before judgment), payable on demand, (i) in the case of overdue principal, at the rate otherwise applicable to such Loan pursuant to Section 2.06 plus 2.00% per annum and (ii) in all other cases, at a rate per annum (computed on the basis of the actual number of days elapsed over a year of 365 or 366 days, as the case may be), equal to the rate that would be applicable to an ABR Loan plus 2.00% per annum.

H. Alternate Rate of Interest. In the event, and on each occasion, that on the day two Business Days prior to the commencement of any Interest Period for a Eurodollar Borrowing the Administrative Agent shall have determined that Dollar deposits in the principal amounts of the Loans comprising such Borrowing are not generally available in the London interbank market, or that the rates at which such Dollar deposits are being offered will not adequately and fairly reflect the cost to the majority of Lenders of making or maintaining Eurodollar Loans during such Interest Period, or that reasonable means do not exist for ascertaining the Adjusted LIBO Rate, the Administrative Agent shall, as soon as practicable thereafter, give written or fax notice of such determination to the Borrower and the Lenders. In the event of any such determination, until the Administrative Agent shall have advised the Borrower and the Lenders that the circumstances giving rise to such notice no longer exist (which notice shall be given promptly upon such circumstances’ ceasing to exist), any request by the Borrower for a Eurodollar Borrowing pursuant to Section 2.03 or 2.10 shall be deemed to be a request for an ABR Borrowing. Each determination by the Administrative Agent under this Section 2.08 shall be conclusive absent manifest error.

I. Termination of Commitments. The Initial Commitments shall automatically terminate upon the making of the Initial Loans on the Closing Date.

 

39


J. Conversion and Continuation of Borrowings. The Borrower shall have the right at any time upon prior irrevocable written notice to the Administrative Agent (a) not later than 12:00 (noon), New York City time, one Business Day prior to conversion, to convert any Eurodollar Borrowing into an ABR Borrowing, (b) not later than 12:00 (noon), New York City time, three Business Days prior to conversion or continuation, to convert any ABR Borrowing into a Eurodollar Borrowing or to continue any Eurodollar Borrowing as a Eurodollar Borrowing for an additional Interest Period, and (c) not later than 12:00 (noon), New York City time, three Business Days prior to conversion, to convert the Interest Period with respect to any Eurodollar Borrowing to another permissible Interest Period, subject in each case to the following:

(1) unless the Administrative Agent shall have notified the Borrower that the primary syndication of the Commitments has been completed (which notice shall be given as promptly as practicable), no ABR Borrowing may be converted into a Eurodollar Borrowing with an Interest Period in excess of one month prior to the date that is 30 days after the Closing Date;

(2) each conversion or continuation shall be made pro rata among the Lenders in accordance with the respective principal amounts of the Loans comprising the converted or continued Borrowing;

(3) if less than all the outstanding principal amount of any Borrowing shall be converted or continued, then each resulting Borrowing shall satisfy the limitations specified in Sections 2.02(a) and 2.02(b) regarding the principal amount and maximum number of Borrowings of the relevant Type;

(4) each conversion shall be effected by each Lender and the Administrative Agent by recording for the account of such Lender the new Loan of such Lender resulting from such conversion and reducing the Loan (or portion thereof) of such Lender being converted by an equivalent principal amount; accrued interest on any Eurodollar Loan (or portion thereof) being converted shall be paid by the Borrower at the time of conversion;

(5) if any Eurodollar Borrowing is converted at a time other than the end of the Interest Period applicable thereto, the Borrower shall pay, upon demand, any amounts due to the Lenders pursuant to Section 2.16;

(6) any portion of a Borrowing maturing or required to be repaid in less than one month may not be converted into or continued as a Eurodollar Borrowing;

(7) any portion of a Eurodollar Borrowing that cannot be converted into or continued as a Eurodollar Borrowing by reason of the immediately preceding clause shall be automatically converted at the end of the Interest Period in effect for such Borrowing into an ABR Borrowing;

(8) no Interest Period may be selected for any Eurodollar Borrowing that would end later than a Repayment Date occurring on or after the first day of such Interest Period if, after giving effect to such selection, the aggregate outstanding amount of (A) the Eurodollar Borrowings comprised of Loans with Interest Periods ending on or prior to such Repayment Date and (B) the ABR Borrowings comprised of Loans would not be at least equal to the principal amount of Borrowings to be paid on such Repayment Date; and

 

40


(9) upon notice to the Borrower from the Administrative Agent given at the request of the Required Lenders, after the occurrence and during the continuance of an Event of Default, no outstanding Loan may be converted into, or continued as, a Eurodollar Loan.

Each notice pursuant to this Section 2.10 shall be irrevocable and shall refer to this Agreement and specify (i) the identity and amount of the Borrowing that the Borrower requests be converted or continued, (ii) whether such Borrowing is to be converted to or continued as a Eurodollar Borrowing or an ABR Borrowing, (iii) if such notice requests a conversion, the date of such conversion (which shall be a Business Day) and (iv) if such Borrowing is to be converted to or continued as a Eurodollar Borrowing, the Interest Period with respect thereto. If no Interest Period is specified in any such notice with respect to any conversion to or continuation as a Eurodollar Borrowing, the Borrower shall be deemed to have selected an Interest Period of one month’s duration. The Administrative Agent shall promptly advise the Lenders of any notice given pursuant to this Section 2.10 and of each Lender’s portion of any converted or continued Borrowing. If the Borrower shall not have given notice in accordance with this Section 2.10 to continue any Borrowing into a subsequent Interest Period (and shall not otherwise have given notice in accordance with this Section 2.10 to convert such Borrowing), such Borrowing shall, at the end of the Interest Period applicable thereto (unless repaid pursuant to the terms hereof), automatically be converted to an ABR Borrowing.

K. Repayment of Loans. i. (i) The Borrower shall pay to the Administrative Agent, for the account of the Initial Lenders, on the dates set forth below, or if any such date is not a Business Day, on the next preceding Business Day (each such date being called a “Repayment Date”), a principal amount of the Initial Loans (as adjusted from time to time pursuant to Sections 2.12 and 2.13) equal to the amount set forth below for such date, together in each case with accrued and unpaid interest on the principal amount to be paid to but excluding the date of such payment:

 

Repayment Date

   Amount  

September 30, 2014

   $ 1,937,500.00   

December 31, 2014

   $ 1,937,500.00   

March 31, 2015

   $ 1,937,500.00   

June 30, 2015

   $ 1,937,500.00   

September 30, 2015

   $ 1,937,500.00   

December 31, 2015

   $ 1,937,500.00   

March 31, 2016

   $ 1,937,500.00   

June 30, 2016

   $ 1,937,500.00   

September 30, 2016

   $ 1,937,500.00   

December 31, 2016

   $ 1,937,500.00   

March 31, 2017

   $ 1,937,500.00   

June 30, 2017

   $ 1,937,500.00   

September 30, 2017

   $ 1,937,500.00   

December 31, 2017

   $ 1,937,500.00   

March 31, 2018

   $ 1,937,500.00   

June 30, 2018

   $ 1,937,500.00   

September 30, 2018

   $ 1,937,500.00   

December 31, 2018

   $ 1,937,500.00   

 

41


and (ii) in the event that any Incremental Loans are made on an Increased Amount Date, the Borrower shall repay such Incremental Loans on the dates and in the amounts set forth in the Incremental Assumption Agreement.

ii. To the extent not previously paid, all Loans shall be due and payable on the Maturity Date or the applicable Incremental Loan Maturity Date, as the case may be, together with accrued and unpaid interest on the principal amount to be paid to but excluding the date of payment.

iii. All repayments pursuant to this Section 2.11 shall be subject to Section 2.16, but shall otherwise be without premium or penalty.

L. Voluntary Prepayment. i. Subject to the concurrent payment of the Applicable Premium, if any, the Borrower may at any time and from time to time prepay any Borrowing, in whole or in part, upon at least three Business Days’ prior written or fax notice (or telephone notice promptly confirmed by written or fax notice) in the case of Eurodollar Loans, or written or fax notice (or telephone notice promptly confirmed by written or fax notice) at least one Business Day prior to the date of prepayment in the case of ABR Loans, to the Administrative Agent before 12:00 (noon), New York City time; provided, however, that each partial prepayment shall be in an amount that is an integral multiple of $1,000,000 and not less than $1,000,000.

ii. Voluntary prepayments of Loans under Section 2.12(a) shall be applied against the remaining scheduled installments of principal due in respect of the Loans under Section 2.11 as directed by the Borrower and, absent such direction, in direct order of maturity.

iii. Each notice of prepayment under Section 2.12(a) shall specify the prepayment date and the principal amount of each Borrowing (or portion thereof) to be prepaid, shall be irrevocable and shall commit the Borrower to prepay such Borrowing by the amount stated therein on the date stated therein; provided, however, that if such prepayment would have resulted from a refinancing of all or any part of the Loans, which refinancing shall not be consummated or shall otherwise by delayed, then the Borrower may revoke such notice by written notice to the Administrative Agent no later than 12:00 (noon), New York City time, on the date of prepayment and/or extend the prepayment date by not more than five Business Days; provided further, however, that the provisions of Section 2.16 shall apply with respect to any such revocation or extension. All prepayments under this Section 2.12 shall be subject to Section 2.16. All prepayments under this Section 2.12 shall be accompanied by the concurrent payment of the accrued and unpaid interest on the principal amount to be prepaid to but excluding the date of payment and the Applicable Premium, if any.

 

42


M. Mandatory Prepayments. i. Not later than the fifth Business Day following the receipt of Net Cash Proceeds in respect of any individual Asset Sale or series of related Asset Sales (other than any Disposition or series of Dispositions made pursuant to clauses (b), (c), (d), (e), (f), (g), (h), (i), (j) and (l) through (p) of Section 6.05), the Borrower shall apply 100% of the Net Cash Proceeds received with respect thereto to prepay outstanding Loans.

ii. In the event that the Borrower or any Subsidiary Guarantor or any Subsidiary of any such Loan Party shall receive Net Cash Proceeds from the issuance or incurrence of Indebtedness for money borrowed of any such Loan Party or any Subsidiary of any such Loan Party (other than any cash proceeds from the issuance of Indebtedness permitted pursuant to Section 6.01), the Borrower shall substantially simultaneously with (and in any event not later than the fifth Business Day following) the receipt of such Net Cash Proceeds by such Loan Party or such Subsidiary, apply an amount equal to 100% of such Net Cash Proceeds to prepay outstanding Loans.

iii. Not later than 125 days after the end of each fiscal year of the Borrower, commencing with the fiscal year ending on December 31, 2014, the Borrower shall prepay outstanding Loans in an aggregate principal amount equal to (i) 50% of Excess Cash Flow for the fiscal year then ended; provided, that such percentage shall be reduced to (x) 25% if the Leverage Ratio as of the last day of such fiscal year was less than 3.00 to 1.00 and greater than or equal to 2.00 to 1.00 and (y) 0% if the Leverage Ratio as of the last day of such fiscal year was less than 2.00 to 1.00, minus (ii) the sum of all voluntary prepayments of, and purchases by the Borrower or Holdings pursuant to Section 9.04(k) of, Loans during such fiscal year.

iv. All prepayments of Borrowings under Section 2.13(a), (b) and (c) shall be accompanied by the concurrent payment of the accrued and unpaid interest on the principal amount to be prepaid to but excluding the date of payment.

v. Mandatory prepayments of Loans (i) pursuant to clause (c) of this Section 2.13 shall be applied against the remaining scheduled installments of principal due in respect of the Loans under Section 2.11 as directed by the Borrower and, absent such direction, in direct order of maturity, and (ii) pursuant to clauses (a) and (b) of this Section 2.13 shall be applied first in direct order of maturity to repayments thereof required pursuant to Section 2.11 in the 24-month period following the date such prepayment becomes payable and second pro rata against the remaining scheduled installments of principal due in respect of the Loans under Section 2.11.

vi. The Borrower shall deliver to the Administrative Agent, (i) at the time of each prepayment required under this Section 2.13, a certificate signed by a Financial Officer of the Borrower setting forth in reasonable detail the calculation of the amount of such prepayment and (ii) at least three Business Days prior to such prepayment, written notice of such prepayment. Each notice of prepayment shall specify the prepayment date, the Type of each Loan being prepaid and the principal amount of each Loan (or portion thereof) to be prepaid. All prepayments of Borrowings under this Section 2.13 shall be subject to Section 2.16. The Administrative Agent will promptly notify each Lender of the contents of each such prepayment notice. Notwithstanding any of the provisions of this Section 2.13, so long as no Event of Default shall have occurred and be continuing, if any prepayment of Eurodollar Loans is required to be made under this Section 2.13, other than on the last day of the Interest Period

 

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therefor, the Borrower may, in its sole discretion, deposit the amount of any such prepayment otherwise required to be made thereunder with the Administrative Agent until the last day of such Interest Period, at which time the Administrative Agent shall be authorized (without any further action by or notice to or from any Borrower or any other Loan Party) to apply such amount to the prepayment of such Loans in accordance with this Section 2.13. Upon the occurrence and during the continuance of any Event of Default, the Administrative Agent shall also be authorized (without any further action by or notice to or from any Borrower or any other Loan Party) to apply such amount to the prepayment of the outstanding Loans in accordance with this Section 2.13.

vii. Each Lender may elect, by written notice to the Administrative Agent no later than 5:00 p.m., New York City time, one Business Day after the date of delivery of notice regarding such prepayment pursuant to paragraph (f) above, to decline all (but not less than all) of any mandatory prepayment of its Loans pursuant to this Section 2.13 (such declined amounts, the “Declined Proceeds”). Any Declined Proceeds may be retained by the Borrower.

N. Reserve Requirements; Change in Circumstances. i. If any Change in Law shall (i) impose, modify or deem applicable any reserve, special deposit, compulsory loan, insurance charge or similar requirement against assets of, deposits with or for the account of, or credit extended or participated in by, any Lender (except any reserve requirement reflected in the Adjusted LIBO Rate); (ii) subject any Recipient to any Taxes (other than (A) Indemnified Taxes, (B) Taxes described in clauses (b) through (d) of the definition of Excluded Taxes) and (C) Connection Income Taxes) on its loans, loan principal, commitments, or other obligations, or its deposits, reserves, other liabilities or capital attributable thereto; or (iii) impose on any Lender or the London interbank market any other condition, cost or expense (other than Taxes) affecting this Agreement or Loans made by such Lender; and the result of any of the foregoing shall be to increase the cost to such Lender or such other Recipient of making, converting to, continuing or maintaining any Loan or of maintaining its obligation to make any such Loan, or to reduce the amount of any sum received or receivable by such Lender or other Recipient hereunder (whether of principal, interest or any other amount) then, upon request of such Lender or other Recipient setting forth in reasonable detail such increased costs or reduction, the Borrower will pay to such Lender or other Recipient, as the case may be, such additional amount or amounts as will compensate such Lender or other Recipient, as the case may be, for such additional costs incurred or reduction suffered.

ii. If any Lender determines that any Change in Law affecting such Lender or any lending office of such Lender or such Lender’s holding company, if any, regarding capital or liquidity requirements, has or would have the effect of reducing the rate of return on such Lender’s capital or on the capital of such Lender’s holding company, if any, as a consequence of this Agreement, the Commitments of such Lender or the Loans made by such Lender to a level below that which such Lender or such Lender’s holding company could have achieved but for such Change in Law (taking into consideration such Lender’s policies and the policies of such Lender’s holding company with respect to capital adequacy), then from time to time, upon request of such Lender setting forth in reasonable detail such reduced rate of return, the Borrower will pay to such Lender such additional amount or amounts as will compensate such Lender or such Lender’s holding company for any such reduction suffered.

 

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iii. A certificate of a Lender setting forth the amount or amounts necessary to compensate such Lender or its holding company, as the case may be, as specified in paragraph (a) or (b) of this Section and delivered to the Borrower, shall be conclusive absent manifest error. The Borrower shall pay such Lender the amount shown as due on any such certificate within 15 days after receipt thereof.

iv. Failure or delay on the part of any Lender to demand compensation pursuant to this Section shall not constitute a waiver of such Lender’s right to demand such compensation; provided that the Borrower shall not be required to compensate a Lender pursuant to this Section for any increased costs incurred or reductions suffered more than 90 days prior to the date that such Lender notifies the Borrower of the Change in Law giving rise to such increased costs or reductions, and of such Lender’s intention to claim compensation therefor (except that, if the Change in Law giving rise to such increased costs or reductions is retroactive, then the 90 day period referred to above shall be extended to include the period of retroactive effect thereof).

O. Change in Legality. i. Notwithstanding any other provision of this Agreement, if any Change in Law shall make it unlawful for any Lender to make or maintain any Eurodollar Loan or to give effect to its obligations as contemplated hereby with respect to any Eurodollar Loan, then, by written notice to the Borrower and to the Administrative Agent and until such circumstances no longer exist:

(1) such Lender may declare that Eurodollar Loans will not thereafter (for the duration of such unlawfulness) be made by such Lender hereunder (or be continued for additional Interest Periods) and ABR Loans will not thereafter (for such duration) be converted into Eurodollar Loans, whereupon any request for a Eurodollar Borrowing (or to convert an ABR Borrowing to a Eurodollar Borrowing or to continue a Eurodollar Borrowing for an additional Interest Period) shall, as to such Lender only, be deemed a request for an ABR Loan (or a request to continue an ABR Loan as such for an additional Interest Period or to convert a Eurodollar Loan into an ABR Loan, as the case may be), unless such declaration shall be subsequently withdrawn; and

(2) such Lender may require that all outstanding Eurodollar Loans made by it be converted to ABR Loans, in which event all such Eurodollar Loans shall be automatically converted to ABR Loans as of the effective date of such notice as provided in paragraph (b) below.

In the event any Lender shall exercise its rights under (i) or (ii) above, all payments and prepayments of principal that would otherwise have been applied to repay the Eurodollar Loans that would have been made by such Lender or the converted Eurodollar Loans of such Lender shall instead be applied to repay the ABR Loans made by such Lender in lieu of, or resulting from the conversion of, such Eurodollar Loans.

ii. For purposes of this Section 2.15, a notice to the Borrower by any Lender shall be effective as to each Eurodollar Loan made by such Lender, if lawful, on the last day of the Interest Period then applicable to such Eurodollar Loan; in all other cases such notice shall be effective on the date of receipt by the Borrower.

 

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P. Breakage. The Borrower shall indemnify each Lender against any loss or expense that such Lender actually sustains or incurs as a consequence of (a) any event, other than a default by such Lender in the performance of its obligations hereunder, which results in (i) such Lender receiving or being deemed to receive any amount on account of the principal of any Eurodollar Loan prior to the end of the Interest Period in effect therefor, (ii) the conversion of any Eurodollar Loan to an ABR Loan, or the conversion of the Interest Period with respect to any Eurodollar Loan, in each case other than on the last day of the Interest Period in effect therefor, or (iii) any Eurodollar Loan to be made by such Lender (including any Eurodollar Loan to be made pursuant to a conversion or continuation under Section 2.10) not being made after notice of such Loan shall have been given by the Borrower hereunder (any of the events referred to in this clause (a) being called a “Breakage Event”) or (b) any default in the making of any payment or prepayment required to be made hereunder on the date set forth in the applicable notice with respect thereto from the Borrower. In the case of any Breakage Event, such loss shall include an amount equal to the excess of (i) its cost of obtaining funds for the Eurodollar Loan that is the subject of such Breakage Event for the period from the date of such Breakage Event to the last day of the Interest Period in effect (or that would have been in effect) for such Loan over (ii) the amount of interest realized by such Lender in redeploying the funds released or not utilized by reason of such Breakage Event for such period. A certificate of any Lender setting forth any amount or amounts which such Lender is entitled to receive pursuant to this Section 2.16 shall be delivered to the Borrower and shall be conclusive absent manifest error.

Q. Pro Rata Treatment. Subject to Section 2.13(g), Section 9.04(k), and the relevant terms of any Incremental Assumption Agreement, the express provisions of this Agreement which require, or permit, differing payments to be made to Non-Defaulting Lenders as opposed to Defaulting Lenders, and as required under Section 2.15, each Borrowing, each payment or prepayment of principal of any Borrowing, each payment of interest on the Loans and each conversion of any Borrowing to or continuation of any Borrowing as a Borrowing of any Type shall be allocated pro rata among the Lenders in accordance with their respective Commitments under the relevant Facility or Facilities (or, if such Commitments shall have expired or been terminated, in accordance with the respective principal amounts of their outstanding Loans under the relevant Facility or Facilities). Each Lender agrees that in computing such Lender’s portion of any Borrowing to be made hereunder, the Administrative Agent may, in its discretion, round each Lender’s percentage of such Borrowing to the next higher or lower whole Dollar amount.

R. Sharing of Setoffs. Each Lender agrees that if it shall, through the exercise of a right of banker’s lien, setoff or counterclaim against the Borrower or any other Loan Party, or pursuant to a secured claim under Section 506 of Title 11 of the United States Bankruptcy Code or other security or interest arising from, or in lieu of, such secured claim, received by such Lender under any applicable bankruptcy, insolvency or other similar law or otherwise, or by any other means, obtain payment (voluntary or involuntary) in respect of any Loan or Loans as a result of which the unpaid principal portion of its Loans shall be proportionately less than the unpaid principal portion of the Loans of any other Lender, it shall be deemed simultaneously to have purchased from such other Lender at face value, and shall promptly pay to such other Lender the purchase price for, a participation in the Loans of such other Lender, so that the aggregate unpaid principal amount of the Loans and participations in Loans held by each Lender shall be in the same proportion to the aggregate unpaid principal amount of all Loans then outstanding as the principal amount of its Loans prior to such exercise of banker’s lien, setoff or

 

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counterclaim or other event was to the principal amount of all Loans outstanding prior to such exercise of banker’s lien, setoff or counterclaim or other event; provided, however, that (i) if any such purchase or purchases or adjustments shall be made pursuant to this Section 2.18 and the payment giving rise thereto shall thereafter be recovered, such purchase or purchases or adjustments shall be rescinded to the extent of such recovery and the purchase price or prices or adjustment restored without interest, and (ii) the provisions of this Section 2.18 shall not be construed to apply to any payment made by the Borrower pursuant to and in accordance with the express terms of this Agreement or any payment obtained by a Lender as consideration for the assignment of or sale of a participation in any of its Loans to any assignee or participant, including to the Borrower or Holdings pursuant to Section 9.04(k). The Borrower expressly consents to the foregoing arrangements and agrees that any Lender holding a participation in a Loan deemed to have been so purchased may exercise any and all rights of banker’s lien, setoff or counterclaim with respect to any and all moneys owing by the Borrower to such Lender by reason thereof as fully as if such Lender had made a Loan directly to the Borrower in the amount of such participation.

S. Payments. i. The Borrower shall make each payment (including principal of or interest on any Borrowing or any Fees or other amounts) hereunder and under any other Loan Document not later than 2:00 pm, New York City time, on the date when due in immediately available Dollars, without setoff, defense or counterclaim. Any amounts received after such time on any date may, in the discretion of the Administrative Agent, be deemed to have been received on the next succeeding Business Day for purposes of calculating interest thereon. Each such payment shall be made to the Administrative Agent at its offices at Eleven Madison Avenue, New York, NY 10010. The Administrative Agent shall promptly distribute to each Lender any payments received by the Administrative Agent on behalf of such Lender.

ii. Except as otherwise expressly provided herein, whenever any payment (including principal of or interest on any Borrowing or any Fees or other amounts) hereunder or under any other Loan Document shall become due, or otherwise would occur, on a day that is not a Business Day, such payment may be made on the next succeeding Business Day, and such extension of time shall in such case be included in the computation of interest or Fees, if applicable.

T. Taxes. i. Any and all payments by or on account of any obligation of any Loan Party under any Loan Document shall be made without deduction or withholding for any Taxes, except as required by applicable law. If any applicable law (as determined in the good faith discretion of an applicable Withholding Agent) requires the deduction or withholding of any Tax from any such payment by a Withholding Agent, then the applicable Withholding Agent shall be entitled to make such deduction or withholding and shall timely pay the full amount deducted or withheld to the relevant Governmental Authority in accordance with applicable law and, if such Tax is an Indemnified Tax, then the sum payable by the applicable Loan Party shall be increased as necessary so that after such deduction or withholding has been made (including such deductions and withholdings applicable to additional sums payable under this Section 2.20) the applicable Recipient receives an amount equal to the sum it would have received had no such deduction or withholding been made.

 

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ii. In addition, the Loan Parties shall timely pay to the relevant Governmental Authority in accordance with applicable law, or at the option of the Administrative Agent timely reimburse it for the payment of, any Other Taxes.

iii. The Loan Parties shall jointly and severally indemnify the Administrative Agent and each Lender, within twenty (20) days after written demand therefor, for the full amount of any Indemnified Taxes (including Indemnified Taxes imposed or asserted on or attributable to amounts payable under this Section) payable or paid by such Recipient or required to be withheld or deducted from a payment to such Recipient and any reasonable expenses arising therefrom or with respect thereto, whether or not such Indemnified Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority; provided that a Loan Party shall not be required to indemnify a Recipient for Indemnified Taxes pursuant to this Section 2.20(c) unless such Recipient notifies the Loan Parties of the indemnification claim for such Indemnified Taxes no later than two months after the latest of (x) the Maturity Date, (y) the date on which the statute of limitations with respect to such Indemnified Taxes expires (taking into account any extensions thereof) and (z) the date on which such Recipient has made payment of such Indemnified Taxes. A certificate as to the amount of such payment or liability delivered to the Borrower by a Lender (with a copy to the Administrative Agent), or by the Administrative Agent on its own behalf or on behalf of a Lender, shall be conclusive absent manifest error.

iv. As soon as practicable after any payment of Indemnified Taxes or Other Taxes by any Loan Party to a Governmental Authority, such Loan Party shall deliver to the Administrative Agent the original or a certified copy of a receipt issued by such Governmental Authority evidencing such payment, a copy of the return reporting such payment or other evidence of such payment reasonably satisfactory to the Administrative Agent.

v.

(1) Any Lender that is entitled to an exemption from or reduction of withholding Tax with respect to payments made under any Loan Document shall deliver to the Borrower and the Administrative Agent, at the time or times reasonably requested by the Borrower or the Administrative Agent, such properly completed and executed documentation reasonably requested by the Borrower or the Administrative Agent as will permit such payments to be made without withholding or at a reduced rate of withholding. In addition, any Lender, if reasonably requested by the Borrower or the Administrative Agent, shall deliver such other documentation prescribed by applicable law or reasonably requested by the Borrower or the Administrative Agent as will enable the Borrower or the Administrative Agent to determine whether or not such Lender is subject to backup withholding or information reporting requirements. Notwithstanding anything to the contrary in the preceding two sentences, the completion, execution and submission of such documentation (other than such documentation set forth in Section 2.20(e)(ii)(A), (ii)(B) and (ii)(D) below) shall not be required if in the Lender’s reasonable judgment such completion, execution or submission would subject such Lender to any material unreimbursed cost or expense or would materially prejudice the legal or commercial position of such Lender.

 

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(2) Without limiting the generality of the foregoing,

1) any Lender that is a U.S. Person shall deliver to the Borrower and the Administrative Agent on or prior to the date on which such Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), properly completed and duly executed originals of IRS Form W-9 certifying that such Lender is exempt from U.S. Federal backup withholding Tax;

2) any Foreign Lender shall, to the extent it is legally entitled to do so, deliver to the Borrower and the Administrative Agent (in such number of copies as shall be requested by the recipient) on or prior to the date on which such Foreign Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), whichever of the following is applicable:

a) in the case of a Foreign Lender claiming the benefits of an income tax treaty to which the United States is a party (x) with respect to payments of interest under any Loan Document, properly completed and duly executed originals of IRS Form W-8BEN or IRS Form W-8BEN-E (or any successor form) establishing an exemption from, or reduction of, U.S. Federal withholding Tax pursuant to the “interest” article of such tax treaty and (y) with respect to any other applicable payments under any Loan Document, IRS Form W-8BEN or IRS Form W-8BEN-E (or any successor form) establishing an exemption from, or reduction of, U.S. Federal withholding Tax pursuant to the “business profits” or “other income” article of such tax treaty;

b) properly completed and duly executed originals of IRS Form W-8ECI;

c) in the case of a Foreign Lender claiming the benefits of the exemption for portfolio interest under Section 881(c) of the Code, (x) a certificate substantially in the form of Exhibit G-1 to the effect that such Foreign Lender is not a “bank” within the meaning of Section 881(c)(3)(A) of the Code, a “10 percent shareholder” of the Borrower within the meaning of Section 881(c)(3)(B) of the Code, or a “controlled foreign corporation” described in Section 881(c)(3)(C) of the Code (a “U.S. Tax Compliance Certificate”) and (y) executed originals of IRS Form W-8BEN or IRS Form W-8BEN-E (or any successor form); or

d) to the extent a Foreign Lender is not the beneficial owner, properly completed and duly executed originals of IRS Form W-8IMY, accompanied by IRS Form W-8ECI, IRS Form W-8BEN, IRS Form W-8BEN-E (or any successor form), a U.S. Tax Compliance Certificate substantially in the form of Exhibit G-2 or Exhibit G-3, IRS Form W-9, and/or other certification documents from each beneficial owner, as

 

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applicable; provided that if the Foreign Lender is a partnership and one or more direct or indirect partners of such Foreign Lender are claiming the portfolio interest exemption, such Foreign Lender may provide a U.S. Tax Compliance Certificate substantially in the form of Exhibit G-4 on behalf of each such direct and indirect partner;

3) any Foreign Lender shall, to the extent it is legally entitled to do so, deliver to the Borrower and the Administrative Agent (in such number of copies as shall be requested by the recipient) on or prior to the date on which such Foreign Lender becomes a Lender under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower or the Administrative Agent), executed originals of any other form prescribed by applicable law as a basis for claiming exemption from or a reduction in U.S. Federal withholding Tax, duly completed, together with such supplementary documentation as may be prescribed by applicable law to permit the Borrower or the Administrative Agent to determine the withholding or deduction required to be made;

4) if a payment made to a Lender under any Loan Document would be subject to U.S. Federal withholding Tax imposed by FATCA if such Lender were to fail to comply with the applicable reporting requirements of FATCA (including those contained in Section 1471(b) or 1472(b) of the Code, as applicable), such Lender shall deliver to the Borrower and the Administrative Agent at the time or times prescribed by law and at such time or times reasonably requested by the Borrower or the Administrative Agent such documentation prescribed by applicable law (including as prescribed by Section 1471(b)(3)(C)(i) of the Code) and such additional documentation reasonably requested by the Borrower or the Administrative Agent as may be necessary for the Borrower and the Administrative Agent to comply with their obligations under FATCA and to determine that such Lender has complied with such Lender’s obligations under FATCA or to determine the amount to deduct and withhold from such payment. Solely for purposes of this clause (D), “FATCA” shall include any amendments made to FATCA after the date of this Agreement; and

5) the Administrative Agent (in its capacity as Administrative Agent) shall, to the extent it is legally entitled to do so, deliver to the Borrower on or prior to the date on which the Administrative Agent becomes the Administrative Agent under this Agreement (and from time to time thereafter upon the reasonable request of the Borrower) two properly completed and duly executed copies of (i) in the case of an Administrative Agent that is a U.S. Person, IRS Form W-9 or (ii) in the case of an Administrative Agent that is not a U.S. Person, IRS Form W-8IMY.

Each Lender agrees that if any form or certification it previously delivered expires or becomes obsolete or inaccurate in any respect, it shall update such form or certification or promptly notify the Borrower and the Administrative Agent in writing of its legal inability to do so.

 

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vi. Each Lender shall severally indemnify the Administrative Agent, within 10 days after written demand therefor, for (i) any Indemnified Taxes attributable to such Lender (but only to the extent that any Loan Party has not already indemnified the Administrative Agent for such Indemnified Taxes and without limiting the obligation of the Loan Parties to do so), (ii) any Taxes attributable to such Lender’s failure to comply with the provisions of Section 9.04 relating to the maintenance of a Participant Register or SPV Register and (iii) any Excluded Taxes attributable to such Lender, in each case, that are payable or paid by the Administrative Agent in connection with any Loan Document, and any reasonable expenses arising therefrom or with respect thereto, whether or not such Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. A certificate as to the amount of such payment or liability delivered to any Lender by the Administrative Agent shall be conclusive absent manifest error. Each Lender hereby authorizes the Administrative Agent to set off and apply any and all amounts at any time owing to such Lender under any Loan Document or otherwise payable by the Administrative Agent to the Lender from any other source against any amount due to the Administrative Agent under this paragraph (f).

vii. If any party determines, in its sole discretion exercised in good faith, that it has received a refund of any Taxes as to which it has been indemnified pursuant to this Section 2.20 (including by the payment of additional amounts pursuant to this Section 2.20), it shall pay to the indemnifying party an amount equal to such refund (but only to the extent of indemnity payments made under this Section 2.20 with respect to the Taxes giving rise to such refund), net of all out-of-pocket expenses (including Taxes) of such indemnified party and without interest (other than any interest paid by the relevant Governmental Authority with respect to such refund). Such indemnifying party, upon the request of such indemnified party, shall repay to such indemnified party the amount paid over pursuant to this paragraph (g) (plus any penalties, interest or other charges imposed by the relevant Governmental Authority) in the event that such indemnified party is required to repay such refund to such Governmental Authority. Notwithstanding anything to the contrary in this paragraph (g), in no event will the indemnified party be required to pay any amount to an indemnifying party pursuant to this paragraph (g) the payment of which would place the indemnified party in a less favorable net after-Tax position than the indemnified party would have been in if the Tax subject to indemnification and giving rise to such refund had not been deducted, withheld or otherwise imposed and the indemnification payments or additional amounts with respect to such Tax had never been paid. This paragraph shall not be construed to require any indemnified party to make available its Tax returns (or any other information relating to its Taxes that it deems confidential) to the indemnifying party or any other Person.

viii. The parties to this Agreement hereby agree that they will treat each Loan prepayment made by the Borrower pursuant to Section 2.13(c) as a pro rata prepayment (within the meaning of U.S. Treasury Regulations Section 1.1275-2(f)) of the Loans in retirement of a portion of such Loans pursuant to U.S. Treasury Regulations Section 1.1272-1(c)(6).

ix. Each party’s obligations under this Section 2.20 shall survive the resignation or replacement of the Administrative Agent or any assignment of rights by, or the replacement of, a Lender, the termination of the Commitments and the repayment, satisfaction or discharge of all obligations under any Loan Document. For purposes of this Section 2.20, the term “applicable law” includes FATCA.

 

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U. Assignment of Commitments Under Certain Circumstances; Duty to Mitigate. i. In the event (i) any Lender delivers a certificate requesting compensation pursuant to Section 2.14, (ii) any Lender delivers a notice described in Section 2.15, (iii) the Borrower is required to pay any additional amount to any Lender or any Governmental Authority on account of any Lender pursuant to Section 2.20, (iv) any Lender is a Non-Consenting Lender, or (v) any Lender is a Defaulting Lender, then, in each case, the Borrower may, at its sole expense and effort (including with respect to the processing and recordation fee referred to in Section 9.04(b)), upon notice to such Lender and the Administrative Agent, require such Lender to transfer and assign, without recourse (in accordance with and subject to the restrictions contained in Section 9.04), all of its interests, rights and obligations under this Agreement to an Eligible Assignee that shall assume such assigned obligations and, with respect to clause (v) above, shall consent to such requested amendment, waiver or other modification of any Loan Documents (which assignee may be another Lender, if a Lender accepts such assignment); provided that (x) such assignment shall not conflict with any law, rule or regulation or order of any court or other Governmental Authority having jurisdiction, (y) the Borrower shall have received the prior written consent of the Administrative Agent, which consent shall not unreasonably be withheld or delayed, and (z) the Borrower or such assignee, as applicable, shall have paid to the affected Lender in immediately available funds an amount equal to the sum of the principal of and interest accrued to the date of such payment on the outstanding Loans of such Lender plus all Fees and other amounts accrued for the account of such Lender hereunder with respect thereto (including any Applicable Premium and any amounts under Sections 2.14 and 2.16); provided further that, if prior to any such transfer and assignment the circumstances or event that resulted in such Lender’s claim for compensation under Section 2.14, notice under Section 2.15 or the amounts payable pursuant to Section 2.20, as the case may be, cease to cause such Lender to suffer increased costs or reductions in amounts received or receivable or reduction in return on capital, or cease to have the consequences specified in Section 2.15, or cease to result in amounts being payable under Section 2.20, as the case may be (including as a result of any action taken by such Lender pursuant to paragraph (b) below), or if such Lender shall waive its right to claim further compensation under Section 2.14 in respect of such circumstances or event or shall withdraw its notice under Section 2.15 or shall waive its right to further payments under Section 2.20 in respect of such circumstances or event or shall consent to the proposed amendment, waiver, consent or other modification, as the case may be, then such Lender shall not thereafter be required to make any such transfer and assignment hereunder. Each Lender hereby grants to the Administrative Agent an irrevocable power of attorney (which power is coupled with an interest) to execute and deliver, on behalf of such Lender as assignor, any Assignment and Acceptance necessary to effectuate any assignment of such Lender’s interests hereunder in the circumstances contemplated by this Section 2.21(a).

ii. If (i) any Lender shall request compensation under Section 2.14, (ii) any Lender delivers a notice described in Section 2.15 or (iii) the Borrower is required to pay any additional amount to any Lender or any Governmental Authority on account of any Lender pursuant to Section 2.20, then such Lender shall use reasonable efforts (which shall not require such Lender to incur an unreimbursed loss or unreimbursed cost or expense or otherwise take any action inconsistent with its internal policies or legal or regulatory restrictions or suffer any disadvantage or burden deemed by it to be significant) (x) to file any certificate or document reasonably requested in writing by the Borrower or (y) to assign its rights and delegate and transfer its obligations hereunder to another of its offices, branches or affiliates, if such filing or assignment

 

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would reduce its claims for compensation under Section 2.14 or enable it to withdraw its notice pursuant to Section 2.15 or would reduce amounts payable pursuant to Section 2.20, as the case may be, in the future. The Borrower hereby agrees to pay all reasonable costs and expenses incurred by any Lender in connection with any such filing or assignment, delegation and transfer.

V. Defaulting Lenders. i. Notwithstanding anything to the contrary contained in this Agreement, if any Lender becomes a Defaulting Lender, then, until such time as such Lender is no longer a Defaulting Lender, to the extent permitted by applicable law:

(1) Such Defaulting Lender’s right to approve or disapprove any amendment, waiver or consent with respect to this Agreement shall be restricted as set forth in the definition of Required Lenders.

(2) Any payment of principal, interest, fees or other amounts received by the Administrative Agent for the account of such Defaulting Lender (whether voluntary or mandatory, at maturity, pursuant to Article VII or otherwise) or received by the Administrative Agent from a Defaulting Lender pursuant to Section 9.06 shall be applied at such time or times as may be determined by the Administrative Agent as follows: first, to the payment of any amounts owing by such Defaulting Lender to the Administrative Agent hereunder; second, as the Borrower may request (so long as no Event of Default exists), to the funding of any Loan in respect of which such Defaulting Lender has failed to fund its portion thereof as required by this Agreement, as determined by the Administrative Agent; third, to the payment of any amounts owing to the Lenders as a result of any judgment of a court of competent jurisdiction obtained by the Administrative Agent or any Lender against such Defaulting Lender as a result of such Defaulting Lender’s breach of its obligations under this Agreement; fourth, so long as no Event of Default exists, to the payment of any amounts owing to the Borrower as a result of any judgment of a court of competent jurisdiction obtained by the Borrower against such Defaulting Lender as a result of such Defaulting Lender’s breach of its obligations under this Agreement; and fifth, provided all amounts owing to the Borrower under “fourth” above have been paid to the Borrower, to such Defaulting Lender or as otherwise directed by a court of competent jurisdiction; provided that if (x) such payment is a payment of the principal amount of any Loans in respect of which such Defaulting Lender has not fully funded its appropriate share, and (y) such Loans were made at a time when the conditions set forth in Section 4.01 were satisfied or waived, such payment shall be applied solely to pay the Loans of all Non-Defaulting Lenders on a pro rata basis prior to being applied to the payment of any Loans of such Defaulting Lender until such time as all Loans are held by the Lenders pro rata in accordance with their Commitments. Any payments, prepayments or other amounts paid or payable to a Defaulting Lender that are applied (or held) to pay amounts owed by a Defaulting Lender pursuant to this Section 2.22(a)(ii) shall be deemed paid to and redirected by such Defaulting Lender, and each Lender irrevocably consents hereto.

ii. If the Borrower and the Administrative Agent agree in writing that a Lender is no longer a Defaulting Lender, the Administrative Agent will so notify the parties hereto, whereupon as of the effective date specified in such notice and subject to any conditions set forth therein, that Lender will, to the extent applicable, purchase at par that portion of outstanding

 

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Loans of the other Lenders or take such other actions as the Administrative Agent may determine to be necessary to cause the Loans to be held pro rata by the Lenders in accordance with their Commitments, whereupon such Lender will cease to be a Defaulting Lender; provided that no adjustments will be made retroactively with respect to fees accrued or payments made by or on behalf of the Borrower while that Lender was a Defaulting Lender; and provided, further, that except to the extent otherwise expressly agreed by the affected parties, no change hereunder from Defaulting Lender to Lender will constitute a waiver or release of any claim of any party hereunder arising from that Lender’s having been a Defaulting Lender.

W. Incremental Commitments. i. The Borrower may, by written notice to the Administrative Agent from time to time, request Incremental Commitments in an amount not to exceed in the aggregate the Incremental Amount from one or more Incremental Lenders (which may include any existing Lender) willing to provide such Incremental Loans, in their own discretion; provided, that each Incremental Lender shall be an Eligible Assignee. Such notice shall set forth (i) the amount of the Incremental Commitments being requested, (ii) the date on which such Incremental Commitments are requested to become effective (the “Increased Amount Date”) and (iii) whether such Incremental Commitments are to be commitments to make term loans having the same terms as the Initial Loans or commitments to make term loans with pricing, Yield, maturity date and/or amortization terms different from the Initial Loans (“Other Term Loans”).

(b) The Borrower and each Incremental Lender shall execute and deliver to the Administrative Agent an Incremental Assumption Agreement and such other documentation as the Administrative Agent shall reasonably specify to evidence the Incremental Commitment of such Incremental Lender. Each Incremental Assumption Agreement shall specify the terms of the applicable Incremental Loans; provided, that (i) the Other Term Loans shall rank pari passu or junior in right of payment and/or of security with the Initial Loans (and, to the extent such Other Term Loans are subordinated in right of payment and/or security, such Other Term Loans shall be subject to intercreditor arrangements the terms of which shall be reasonably satisfactory to the Administrative Agent) and, except as to pricing, amortization and final maturity date, shall have (x) the same terms as the Initial Loans, as applicable, or (y) such other terms as shall be reasonably satisfactory to the Administrative Agent, provided that if the Yield in respect of any Other Term Loans secured on a pari passu basis with the Initial Loans shall exceed the Yield in respect of the Initial Loans by more than 0.50%, the Applicable Margin in respect of the Initial Loans (and any Incremental Loans having the same terms as the Initial Loans) shall be increased so that the Yield in respect of such Other Term Loans is not greater than 0.50% above the Yield in respect of the Initial Loans, (ii) the final maturity date of any Other Term Loans shall be no earlier than the Maturity Date, and (iii) the weighted average life to maturity of any Other Term Loans shall be no shorter than the remaining weighted average life to maturity of the Initial Loans (together with any Incremental Loans having the same terms as the Initial Loans). Each of the parties hereto hereby agrees that, upon the effectiveness of any Incremental Assumption Agreement, this Agreement shall be amended to the extent (but only to the extent) necessary to reflect the existence and terms of the Incremental Commitments evidenced thereby. Any such deemed amendment may be memorialized in writing by the Administrative Agent with the Borrower’s consent (not to be unreasonably withheld) and furnished to the other parties hereto.

 

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(c) Notwithstanding the foregoing, no Incremental Commitment shall become effective under this Section 2.23 unless (i) on the date of such effectiveness, the conditions set forth in paragraphs (b) and (c) of Section 4.01 shall be satisfied (with the reference to the “Closing Date” therein being deemed to refer to the Increased Amount Date) and the Administrative Agent shall have received a certificate to that effect dated such date and executed by a Responsible Officer of the Borrower; provided that in the event that the Incremental Commitments are used to finance a Permitted Acquisition, the condition regarding the accuracy of representations and warranties set forth in paragraph (b) of Section 4.01 shall be limited to customary “specified representations” and those representations included in the related acquisition agreement that are material to the interests of the Lenders and only to the extent that the Borrower has the right to terminate its obligations under such acquisition agreement as a result of a breach of such representations, and the condition regarding the absence of a Default or Event of Default required by paragraph (c) of Section 4.01 shall be limited to the Defaults and Events of Default set forth in Section 7.01(b), (c), (g) and (h) and shall be required to be satisfied only at the time of the execution of the relevant acquisition agreement related to such Permitted Acquisition, (ii) the Administrative Agent shall have received customary legal opinions, board resolutions and other customary closing certificates and documentation as required by the relevant Incremental Assumption Agreement and, to the extent required by the Administrative Agent, consistent with those delivered on the Closing Date under Section 4.01 and such additional customary documents and filings (including amendments to the Mortgages and other Security Documents and title endorsement bringdowns) as the Administrative Agent may reasonably require to assure that the Incremental Loans are secured by the Collateral ratably with (or, to the extent agreed by the applicable Incremental Lenders in the applicable Incremental Assumption Agreement, junior to) the Initial Loans (and any Incremental Loans having the same terms as the Initial Loans), and (iii) the Borrower shall be in compliance with the covenant set forth in Section 6.12 determined on a pro forma basis as of the last day of the most recently ended four fiscal quarter period, as if the such Incremental Loans had been outstanding on the last day of such period.

(d) This Section 2.23 shall supersede any provisions in Section 2.17 or Section 9.08 to the contrary.

3.

Representations and Warranties

The Borrower represents and warrants to the Administrative Agent, the Collateral Agent and each of the Lenders that:

A. Organization; Powers. Holdings, the Borrower and each of the Subsidiaries (a) is duly organized, validly existing and in good standing under the laws of the jurisdiction of its organization, (b) has all requisite power and authority, and has all material governmental licenses, authorizations, consents and approvals necessary, to own its material property and assets and to carry on its business as now conducted and as proposed to be conducted, (c) is qualified to do business in, and is in good standing in, every jurisdiction where such qualification is required, except where the failure to do so would not reasonably be expected to result in a Material Adverse Effect, and (d) has the power and authority to execute, deliver and perform its obligations under each of the Loan Documents and each other agreement or instrument contemplated thereby to which it is or will be a party and, in the case of the Borrower, to borrow hereunder.

 

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B. Authorization. The Transactions (a) have been duly authorized by all requisite corporate, limited liability company, limited partnership and other similar action and, if required, stockholder, member or other similar action and (b) will not (i) violate (A) any material provision of law, statute, rule or regulation, or of the certificate or articles of incorporation or formation or other constitutive documents or by-laws or other organizational documents of Holdings, the Borrower or any Subsidiary, (B) any order of any Governmental Authority or (C) any provision of the Holdings Notes Documents or any other any Material Indebtedness (other than the Existing Debt which is being refinanced and replaced on the Closing Date), (ii) be in conflict with, result in a breach of or constitute (alone or with notice or lapse of time or both) a default under, or give rise to any right to accelerate or to require the prepayment, repurchase or redemption of any obligations under the Holdings Notes Documents or any other Material Indebtedness (other than the Existing Debt which is being refinanced and replaced on the Closing Date) or (iii) result in the creation or imposition of any Lien upon or with respect to any material property or assets now owned or hereafter acquired by Holdings, the Borrower or any Subsidiary (other than any Lien created hereunder or under the Security Documents).

C. Enforceability. This Agreement has been duly executed and delivered by Holdings and the Borrower and constitutes, and each other Loan Document when executed and delivered by each Loan Party party thereto will constitute, a legal, valid and binding obligation of such Loan Party enforceable against such Loan Party in accordance with its terms, subject to applicable bankruptcy, insolvency, reorganization, moratorium or other laws affecting creditors’ rights generally and subject to general principles of equity, regardless of whether considered in a proceeding in equity or at law.

D. Governmental Approvals. No action, consent or approval of, registration or filing with or any other action by any Governmental Authority is or will be required in connection with the Transactions, except for (a) the filing of Uniform Commercial Code financing statements, (b) the recordation of the Mortgages, (c) such as have been made or obtained and are in full force and effect, (d) routine filings related to the Loan Parties and the operation of their respective businesses, (e) filings and the recordation of any releases of the Existing Debt, and (f) filings as may be necessary in connection with the exercise of remedies.

E. Financial Statements. i. The Borrower has heretofore furnished to the Lenders its consolidated balance sheets and related statements of income, stockholder’s equity and cash flows (i) as of and for the fiscal years ended December 31, 2012 and December 31, 2013, audited by and accompanied by the opinion of Hein & Associates LLP, independent public accountants, and (ii) as of and for the most recent fiscal quarter ended at least 60 days prior to the Closing Date, certified by its chief financial officer. Such financial statements present fairly, in all material respects, the financial condition and results of operations and cash flows of the Borrower and its consolidated Subsidiaries as of such dates and for such periods. Such balance sheets and the notes thereto disclose all material liabilities, direct or contingent, of the Borrower and its consolidated Subsidiaries as of the dates thereof. Such financial statements were prepared in accordance with GAAP applied on a consistent basis, subject, in the case of unaudited financial statements, to year-end audit adjustments and the absence of footnotes.

 

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ii. The Borrower has heretofore delivered to the Lenders its unaudited pro forma consolidated balance sheet dated as of March 31, 2014, prepared giving effect to the Acquisition and to the other Transactions as if they had occurred on such expected closing date. Such pro forma balance sheet was prepared in good faith by the Borrower, based on the assumptions believed by the Borrower to be reasonable at the time of preparation and delivery thereof based on the information available to the Borrower as of the date of delivery thereof, accurately reflect all adjustments required to be made to give effect to the Acquisition and the other Transactions and present fairly, in all material respects, on a pro forma basis the estimated consolidated financial position of the Borrower and its Consolidated Subsidiaries as of the date of such balance sheet, after giving effect to the Acquisition and the other Transactions.

F. No Material Adverse Change. No event, change or condition has occurred that has had, or could reasonably be expected to have, a material adverse effect on the business, assets, results of operations or financial condition of the Borrower and the Subsidiaries, taken as a whole, since December 31, 2013.

G. Title to Properties; Possession Under Leases. Except as could not reasonably be expected to have a Material Adverse Effect:

i. Each of the Borrower and each Subsidiary has good and defensible title to, or valid leasehold interests in, the Oil and Gas Properties evaluated in the most recently delivered Reserve Report, subject to the Liens expressly permitted by Section 6.02. All such Oil and Gas Properties and all material personal property and assets are free and clear of Liens, other than Liens expressly permitted by Section 6.02. The Borrower or the Subsidiary, as applicable, specified as the owner owns in all material respects the net interests in production attributable to their Oil and Gas Properties as reflected in the most recently delivered Reserve Report, and the ownership of such properties does not in any material respect obligate such Person to bear the costs and expenses relating to the maintenance, development and operations of each such property in an amount in excess of the working interest of each property set forth in the most recently delivered Reserve Report that is not offset by a corresponding proportionate increase in its net revenue interest in such property or the revenues therefrom.

ii. Each of the Borrower and each Subsidiary has complied with all obligations under all material leases to which it is a party and all such leases are in full force and effect. Each of the Borrower and each Subsidiary enjoys peaceful and undisturbed possession under all such material leases.

iii. As of the Closing Date, neither the Borrower nor any Subsidiary has received any notice of, or has any knowledge of, any pending or contemplated condemnation proceeding affecting the Mortgaged Properties or any sale or disposition thereof in lieu of condemnation.

iv. As of the Closing Date, none of the Borrower or any Subsidiary is obligated under any right of first refusal, option or other contractual right to sell, assign or otherwise dispose of any Mortgaged Property or any interest therein except for obligations set forth in the Constellation Agreement.

 

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v. The rights and properties presently owned, leased or licensed by the Borrower and the Subsidiaries including, without limitation, all easements and rights of way, include all rights and properties necessary to permit the Borrower and the Subsidiaries to conduct their businesses in all material respects in the manner as their respective businesses have been conducted prior to the date hereof.

vi. Each of the Borrower and each Subsidiary owns, or is licensed to use, all trademarks, tradenames, copyrights, patents and other intellectual property material to its business, and the use thereof by the Borrower and such Subsidiary does not infringe upon the rights of any other Person, except for any such infringements that, individually or in the aggregate, could not reasonably be expected to result in a Material Adverse Effect. Each of the Borrower and each Subsidiary either owns or has valid licenses or other rights to use all databases, geological data, geophysical data, engineering data, seismic data, maps, interpretations and other technical information used in their businesses as presently conducted, subject to the limitations contained in the agreements governing the use of the same, which limitations are customary for companies engaged in the business of the exploration and production of Hydrocarbons, with such exceptions as, individually or in the aggregate, could not reasonably be expected to have a Material Adverse Effect.

H. Subsidiaries. Schedule 3.08 sets forth as of the Closing Date a list of all Subsidiaries and, with respect to each such Subsidiary, (a) the name of such Subsidiary as listed in the public records of its jurisdiction of organization, (b) the percentage ownership interest of each Loan Party therein, (c) the jurisdiction of organization of such Subsidiary, and (d) the chief executive office for such Subsidiary. The shares of capital stock or other ownership interests so indicated on Schedule 3.08 are fully paid and (other than in respect of any general partner ownership interests) non-assessable and are owned by such Loan Party, directly or indirectly, free and clear of all Liens (other than Liens created under the Security Documents and Liens expressly permitted by Section 6.02).

I. Litigation; Compliance with Laws. i. Except as set forth on Schedule 3.09, there are no actions, suits or proceedings at law or in equity or by or before any Governmental Authority now pending or, to the knowledge of the Borrower, threatened against or affecting the Borrower or any Subsidiary or any business, property or rights of any such Person (i) that involve any Loan Document, the Transactions or any Material Contract or (ii) as to which there is a reasonable possibility of an adverse determination and that, if adversely determined, could reasonably be expected, individually or in the aggregate, to result in a Material Adverse Effect (unless fully covered by insurance with standard deductibles).

ii. Since the Closing Date, there has been no change in the status of the matters disclosed on Schedule 3.09 that, individually or in the aggregate, has resulted in, or could reasonably expect to result in, a Material Adverse Effect.

iii. None of the Borrower or any Subsidiary or any of their respective material properties or assets is in violation of, nor will the continued operation of their material properties and assets as currently conducted violate, any law, rule or regulation (including any zoning, building, Environmental Law, ordinance, code or approval, building permits or any rule or regulation promulgated by the BOEM/BSEE or any other Governmental Authority applicable to

 

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the exploration, production, permitting operation or plugging and abandonment of the Loan Parties’ Oil and Gas Properties) or any restrictions of record or agreements affecting the Mortgaged Property, or is in default with respect to any judgment, writ, injunction, decree or order of any Governmental Authority, where such violation or default could reasonably be expected to result in a Material Adverse Effect.

J. Agreements. i. None of the Borrower or any Subsidiary is a party to any agreement or instrument or subject to any corporate, limited liability company, limited partnership or other similar restriction that has resulted or could reasonably be expected to result in a Material Adverse Effect.

ii. None of the Borrower or any Subsidiary is in default in any manner under any provision of any Material Contract or with respect to any obligation in respect of Material Indebtedness that has resulted or could reasonably be expected to result in a Material Adverse Effect.

K. Federal Reserve Regulations. i. None of Holdings, the Borrower or any Subsidiary is engaged principally, or as one of its important activities, in the business of extending credit for the purpose of buying or carrying Margin Stock.

ii. No part of the proceeds of any Loan will be used, whether directly or indirectly, and whether immediately, incidentally or ultimately, for any purpose that entails a violation of, or that is inconsistent with, the provisions of the Regulations of the Board, including Regulation T, U or X.

L. Investment Company Act. None of Holdings, the Borrower or any Subsidiary is an “investment company” as defined in, or subject to regulation under, the Investment Company Act of 1940.

M. Use of Proceeds. The Borrower will use the proceeds of the Loans only for the purposes specified in the introductory statement to this Agreement.

N. Tax Returns. Except as reflected on Schedule 3.14, the Borrower and each of the Subsidiaries has filed or caused to be filed all Tax returns or other materials required to have been filed by it and has paid or caused to be paid all Taxes due and payable by it and all assessments received by it (and Seller (as defined in the Acquisition Agreement) has represented to the Borrower that Seller has paid all Property-Related Taxes and Production Taxes, in each case, as shown on the Property-Related Tax and Production Tax returns required to be filed with respect to the assets to be acquired by the Borrower under the Acquisition Agreement), except (a) Taxes that are being contested in good faith by appropriate proceedings and for which the Borrower or such Subsidiary, as applicable, shall have set aside on its books adequate reserves in accordance with GAAP and (b) to the extent that the failure to do so could not reasonably be expected to result in a Material Adverse Effect. For purposes of this Section 3.14, capitalized terms not defined in this Agreement shall have the meaning provided to them in the Acquisition Agreement.

O. No Material Misstatements. No written information, report, financial statement, exhibit or schedule furnished by or on behalf of the Borrower to the Administrative Agent or any

 

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Lender in connection with the negotiation of any Loan Document or the transactions contemplated thereby or included therein or delivered pursuant thereto (after giving effect to all supplements and updates thereto from time to time), when furnished and taken as a whole, contained, contains or will contain any material misstatement of fact or omitted, omits or will omit to state any material fact necessary to make the statements therein, in light of the circumstances under which they were, are or will be made, not materially misleading; provided that to the extent any such information, report, financial statement, exhibit or schedule was based upon or constitutes a forecast or projection or pro forma financial information, the Borrower represents only that it acted in good faith and utilized assumptions that were believed to be reasonable at the time of preparation (based upon accounting principles consistent with the historical audited financial statements of the Borrower) and due care in the preparation of such information, report, financial statement, exhibit or schedule; it being understood that any such projections are as to future events and are not to be viewed as facts, that any such projections are subject to significant uncertainties and contingencies, many of which are beyond the Borrower’s control, that no assurance can be given that any particular projections will be realized, that actual results during the period or periods covered by any such projections may differ from the projected results, and such differences may be material, that there are industry-wide risks normally associated with the types of businesses conducted by the Borrower and its subsidiaries, and that projections concerning volume attributable to oil and gas properties and production and cost estimates in reserve reports are necessarily based upon professional opinions, estimates and projections and that the Borrower does not warrant that such opinions, estimates and projections will ultimately prove to have been accurate.

P. Employee Benefit Plans. Each of the Borrower and its ERISA Affiliates is in compliance in all material respects with the applicable provisions of ERISA and the Code and the regulations and published interpretations thereunder, except where any failure to so comply could not reasonably be expected to result in a Material Adverse Effect. No ERISA Event has occurred or is reasonably expected to occur that, when taken together with all other such ERISA Events, could reasonably be expected to result in a Material Adverse Effect. The present value of all benefit liabilities under each Plan (based on the assumptions used for purposes of Accounting Standards Codification Topic 715) did not, as of the last annual valuation date applicable thereto, materially exceed the fair market value of the assets of such Plan, and the present value of all benefit liabilities of all underfunded Plans (based on the assumptions used for purposes of Accounting Standards Codification Topic 715) did not, as of the last annual valuation dates applicable thereto, materially exceed the fair market value of the assets of all such underfunded Plans.

Q. Environmental Matters. i. Except as set forth in Schedule 3.17 and except with respect to any other matters that, individually or in the aggregate, could not reasonably be expected to result in a Material Adverse Effect, none of the Borrower or any of the Subsidiaries (i) has failed to comply with any Environmental Law or to obtain, maintain or comply with any permit, license or other approval required under any Environmental Law, (ii) has become subject to any Environmental Liability, (iii) has received notice of any claim with respect to any Environmental Liability or (iv) knows of any basis for any Environmental Liability.

 

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ii. Since the Closing Date, there has been no change in the status of the matters disclosed on Schedule 3.17 that, individually or in the aggregate, has resulted in a Material Adverse Effect.

R. Insurance. Schedule 3.18 sets forth a true, complete and correct description of all insurance maintained by the Borrower and the Subsidiaries as of the Closing Date. As of the Closing Date, such insurance is in full force and effect and all premiums have been duly paid. The Borrower and its Subsidiaries have insurance in such amounts and covering such risks and liabilities as are in accordance with customary industry practice.

S. Security Documents.

i. The Security Documents, upon execution and delivery thereof by the parties thereto, will create in favor of the Collateral Agent, for the ratable benefit of the Secured Parties, a legal, valid and enforceable security interest in the Collateral described therein and the proceeds thereof to the extent governed by the Uniform Commercial Code and (i) when the Pledged Securities (as defined in the Security Documents) are delivered to the Collateral Agent, the Lien created under Security Documents shall constitute a perfected Lien on, and security interest in, all right, title and interest of the Loan Parties in such Pledged Securities, in each case prior and superior in right to any other Person and (ii) in the case of other Collateral (other than Mortgaged Property) when financing statements in appropriate form are filed in the offices specified on Schedule 3.19(a), the Lien created under the Security Documents will constitute a perfected Lien on, and security interest in, all right, title and interest of the Loan Parties in such Collateral to the extent that such Lien can be perfected by the filing of a financing statement (other than Intellectual Property, as defined in the Security Documents), in each case prior and superior in right to any other Person, subject to Liens expressly permitted by Section 6.02.

ii. The Mortgages are effective to create in favor of the Collateral Agent, for the ratable benefit of the Secured Parties, a legal, valid and enforceable Lien on all of the Loan Parties’ right, title and interest in and to the Mortgaged Property thereunder and the proceeds thereof, and when the Mortgages are filed in the offices specified therein, the Mortgages shall constitute a perfected Lien on, and security interest in, all right, title and interest of the Loan Parties in such Mortgaged Property and the proceeds thereof, in each case prior and superior in right to any other Person, subject to Liens expressly permitted by Section 6.02. As of the Closing Date, the Mortgaged Properties represent at least 80% of the PV-10 Value as reflected in the Initial Reserve Report.

T. Location of Business and Offices. The Borrower’s jurisdiction of organization is the State of Delaware, the name of the Borrower as listed in the public records of its jurisdiction of organization is Energy & Exploration Partners, LLC. As of the Closing Date, the Borrower’s chief executive office is located at Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102.

U. Labor Matters. As of the Closing Date, there are no strikes, lockouts or slowdowns against the Borrower or any Subsidiary pending or, to the knowledge of the Borrower, threatened that could reasonably be expected to result in a Material Adverse Effect. The hours worked by and payments made to employees of the Borrower and the Subsidiaries

 

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have not been in violation of the Fair Labor Standards Act or any other material Federal, state, local or foreign law dealing with such matters, except where any such violation could not reasonably be expected to result in a Material Adverse Effect. All material payments due from the Borrower or any Subsidiary, or for which any claim may be made against the Borrower or any Subsidiary, on account of wages and employee health and welfare insurance and other benefits, have been paid or accrued as a liability on the books of the Borrower or such Subsidiary, except where any failure to so comply could not reasonably be expected to result in a Material Adverse Effect. The consummation of the Transactions will not give rise to any right of termination or right of renegotiation on the part of any union under any collective bargaining agreement to which the Borrower or any Subsidiary is bound that could reasonably be expected to result in a Material Adverse Effect.

V. Solvency. Immediately after the consummation of the Transactions to occur on the Closing Date and immediately following the making of the Loans and after giving effect to the application of the proceeds of the Loans on the Closing Date, (a) the fair value of the assets of the Borrower and its Subsidiaries, taken as a whole, at a fair valuation, will exceed their debts and liabilities, subordinated, contingent or otherwise; (b) the present fair saleable value of the property of the Borrower and its Subsidiaries, taken as a whole, will be greater than the amount that will be required to pay the probable liability of their debts and other liabilities, subordinated, contingent or otherwise, as such debts and other liabilities become absolute and matured; (c) the Borrower and its Subsidiaries, taken as a whole, will be able to pay their debts and liabilities, subordinated, contingent or otherwise, as such debts and liabilities become absolute and matured; and (d) the Borrower and its Subsidiaries, taken as a whole, will not have unreasonably small capital with which to conduct the business in which they are engaged as such business is now conducted and is proposed to be conducted following the Closing Date. The amount of contingent liabilities at any time shall be computed as the amount that, in light of all the facts and circumstances existing at such time, represents the amount that can reasonably be expected to become an actual or matured liability.

W. Sanctioned Persons; Patriot Act; FCPA.

i. None of the Borrower or any Subsidiary nor any director, officer, agent, employee or Affiliate of the Borrower or any Subsidiary is currently subject to any U.S. sanctions administered by the Office of Foreign Assets Control of the U.S. Treasury Department (“OFAC”); and the Borrower will not directly or indirectly use the proceeds of the Loans or otherwise make available such proceeds to any Person, for the purpose of financing the activities of any Person currently subject to any U.S. sanctions administered by OFAC.

ii. Each of the Borrower and each of the Subsidiaries is in compliance with all applicable statutes, regulations and orders of (including any laws relating to terrorism, money laundering, embargoed persons or the USA PATRIOT Act), and all applicable restrictions imposed by, all governmental bodies, domestic or foreign, in respect of the conduct of its business and the ownership of its property (including, without limitation, applicable statutes, regulations, orders and restrictions relating to environmental standards and controls).

iii. Each of the Borrower and each of the Subsidiaries is in compliance in all material respects with the Foreign Corrupt Practices Act, 15 U.S.C.§§ 78dd-1, et seq. (“FCPA”) and any

 

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foreign counterpart thereto applicable to the Borrower or such Subsidiary. None of the Borrower nor any of the Subsidiaries has made a payment, offering, or promise to pay, or authorized the payment of, money or anything of value (i) in order to assist in obtaining or retaining business for or with, or directing business to, any foreign official, foreign political party, party official or candidate for foreign political office, (ii) to a foreign official, foreign political party or party official or any candidate for foreign political office, and (iii) with the intent to induce the recipient to misuse his or her official position to direct business wrongfully to the Borrower or any Subsidiary or to any other Person, in violation of FCPA.

X. Marketing of Production. Except for contracts listed on Schedule 3.24, and thereafter either disclosed in writing to the Administrative Agent or included in the most recently delivered Reserve Report (with respect to all of which contracts the Borrower represents that it or its Subsidiaries are receiving a price for all production sold thereunder which is computed substantially in accordance with the terms of the relevant contract and are not having deliveries curtailed substantially below the subject property’s delivery capacity), no material agreements exist which are not cancelable on one hundred twenty (120) days’ notice or less without penalty or detriment for the sale of production from the Borrower’s or any of its Subsidiaries’ Hydrocarbons (including, without limitation, calls on or other rights to purchase, production, whether or not the same are currently being exercised) that (a) pertain to the sale of production at a fixed price and (b) have a maturity or expiry date of longer than six (6) months.

Y. Hedging Agreements. Schedule 3.25, as of the Closing Date, and after the date hereof, each report required to be delivered by the Borrower pursuant to Section 5.05(d), sets forth, a true and complete list of all Hedging Agreements of the Borrower and each Subsidiary, the material terms thereof (including the type, term, agreement date, settlement date, and notional amounts or volumes), all credit support relating thereto (including any margin required or supplied) and the counterparty to each such agreement, in each case, as of the date hereof or the date of such report, as applicable.

Z. Gas Balancing Agreements and Advance Payment Contracts. Except as set forth on Schedule 3.26, on the Closing Date, on a net basis there are no gas imbalances, take or pay or other prepayments with respect to any of the Loan Parties’ Oil and Gas Properties which would require any Loan Party to deliver, in the aggregate, five percent (5%) or more of the average monthly production of their respective Hydrocarbons (with such average calculated with respect to the twelve (12) months most recently completed prior to the Closing Date) produced on a monthly basis from such Oil and Gas Properties at some future time without then or thereafter receiving full payment therefor.

AA. Absence of Defaults. No Default or Event of Default has occurred and is continuing.

 

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4.

Conditions of Lending

A. Closing Date. The obligations of the Lenders to make Loans hereunder are subject to the satisfaction, or waiver in accordance with this Agreement, of the following conditions on the Closing Date:

i. The Administrative Agent shall have received a notice of the Borrowing to be made on the Closing Date as required by Section 2.03.

ii. The representations and warranties set forth in Article III and in each other Loan Document shall be true and correct in all material respects (other than representations and warranties qualified as to materiality, which will be true and correct in all respects) on and as of the Closing Date with the same effect as though made on and as of such date, except to the extent such representations and warranties expressly relate to an earlier date, in which case they shall be true and correct as of such earlier date.

iii. At the time of and immediately after such Borrowing, no Default or Event of Default shall have occurred and be continuing.

iv. The Administrative Agent shall have received, on behalf of itself, the Collateral Agent, the Arrangers and the Lenders, a favorable written opinion of Bracewell & Giuliani LLP, counsel to the Loan Parties, (A) dated the Closing Date, (B) addressed to the Arrangers, the Agents and the Lenders, and (C) covering such other matters relating to the Loan Documents as the Administrative Agent shall reasonably request, and the Borrower hereby requests such counsel to deliver such opinion.

v. [Reserved].

vi. The Administrative Agent shall have received (i) a copy of the certificate or articles of incorporation or formation, including all amendments thereto, of each Loan Party, certified, as of a recent date by the Secretary of State of the state of its formation, and a certificate as to the good standing of each Loan Party as of a recent date, from such Secretary of State; (ii) a certificate of a Responsible Officer of each Loan Party dated the Closing Date and certifying (A) that attached thereto is a true and complete copy of the governing documents of such Loan Party as in effect on the Closing Date and at all times since a date prior to the date of the resolutions described in clause (B) below, (B) that attached thereto is a true and complete copy of resolutions duly adopted by the members, board of directors or other appropriate governing body of such Loan Party authorizing the execution, delivery and performance of the Loan Documents to which such Person is a party and, in the case of the Borrower, the borrowings hereunder, and that such resolutions have not been modified, rescinded or amended and are in full force and effect, (C) that the certificate or articles of incorporation of such Loan Party have not been amended since the date of the last amendment thereto shown on the certificate of good standing furnished pursuant to clause (i) above, and (D) as to the incumbency and specimen signature of each officer executing any Loan Document or any other document delivered in connection herewith on behalf of such Loan Party; and (iii) a certificate of another officer as to the incumbency and specimen signature of the Responsible Officer executing the certificate pursuant to clause (ii) above.

vii. The Administrative Agent shall have received a certificate, dated the Closing Date and signed by a Responsible Officer of the Borrower, (i) certifying compliance with the conditions precedent set forth in paragraphs (b) and (c) of this Section 4.01, (ii) listing all of the Material Contracts and certifying that copies of the same have been provided to the Administrative Agent, (iii) certifying that no default or event of default under any such Material

 

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Contract has occurred and is continuing or would result from the proposed Borrowing, and (iv) certifying that no default or event of default under the Holding Notes Documents has occurred and is continuing or would result from the proposed Borrowing.

viii. The Administrative Agent and the Arrangers shall have received all Fees and other amounts due and payable on or prior to the Closing Date (or arrangements for the netting of such Fees and other amounts due and payable on the Closing Date shall have been made), including, to the extent invoiced at least two Business Days prior to the Closing Date, reimbursement or payment of all reasonable and documented legal fees and all out-of-pocket expenses required to be reimbursed or paid by the Borrower hereunder or under any other Loan Document.

ix. The Administrative Agent shall have received each of (i) this Agreement and (ii) the Security Documents, in each case, duly executed by each Loan Party and each other party that is to be a party thereto and each such document shall be in full force and effect on the Closing Date.

x. The Collateral Agent shall have received the results of a search of the Uniform Commercial Code filings (or equivalent filings) made with respect to the Loan Parties in the states (or other jurisdictions) of formation of such Persons, in which the chief executive office of each such Person is located and in the other jurisdictions in which such Persons maintain material Oil and Gas Properties, together with copies of any financing statements (or similar documents) disclosed by such search, and accompanied by evidence satisfactory to the Collateral Agent that the Liens indicated in any such financing statement (or similar document) would be permitted under Section 6.02 or have been or will be released or terminated contemporaneously with the funding of the Loans on the Closing Date.

xi. The Administrative Agent shall have received the Initial Reserve Report which shall be in form and substance reasonably acceptable to the Administrative Agent.

xii. (i) Each of the Mortgages shall have been duly executed by the parties thereto and delivered to the Collateral Agent and shall be in full force and effect, (ii) each of such Mortgaged Properties shall not be subject to any Lien other than Liens expressly permitted by Section 6.02 and Liens that will be released or terminated contemporaneously with the funding of the Loans on the Closing Date (including the Liens that secure the Existing Debt), (iii) arrangements reasonably satisfactory to the Collateral Agent for the recordings of the Mortgages in the recording offices specified on Schedule 3.19(b) shall have been made and (iv) the Collateral Agent shall have received such other documents required to be furnished pursuant to the terms of the Mortgages or as reasonably requested by the Collateral Agent or the Lenders.

xiii. The Administrative Agent shall have received a copy of, or a certificate as to coverage under, the insurance policies required by Section 5.03 and the applicable provisions of the Security Documents, each of which shall be endorsed or otherwise amended to include a customary lender’s loss payable endorsement and to name the Collateral Agent as additional insured, in form and substance satisfactory to the Administrative Agent.

 

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xiv. The Administrative Agent shall have received such title information as the Administrative Agent may reasonably require satisfactory to the Administrative Agent setting forth the status of title to at least 80% of the PV-10 Value as reflected in the Initial Reserve Report.

xv. [Reserved].

xvi. The Acquisition shall have been, or substantially contemporaneously with the initial funding of the Loans on the Closing Date shall be, consummated in accordance with applicable law, the Acquisition Agreement and all other related documentation (without giving effect to any waivers, amendments or other modifications to or of such documents that are adverse to the Lenders and not approved by the Required Lenders). The Administrative Agent shall have received copies of the Acquisition Agreement and all material certificates, opinions and other documents delivered thereunder, certified by a Financial Officer as being complete and correct.

xvii. Prior to or substantially concurrently with the initial funding of the Loans, (i) all commitments under the Existing Debt shall have been terminated, (ii) all principal, interest and other amounts accrued or owing thereunder shall have been refinanced and replaced and (iii) all guarantees and Liens granted in respect thereof shall have been released and the terms and conditions of any such release shall be reasonably satisfactory to the Administrative Agent. Immediately after giving effect to the Transactions and the other transactions contemplated hereby, the Borrower and the Subsidiaries shall have outstanding no Indebtedness or preferred stock other than (i) Indebtedness outstanding under this Agreement and (ii) other Indebtedness permitted to exist under Section 6.01.

xviii. The Lenders shall have received the financial statements and opinion referred to in Section 3.05, none of which shall demonstrate a material adverse change in the financial condition of the Borrower from (and shall not otherwise be materially inconsistent with) the financial statements or forecasts previously provided to the Lenders.

xix. The Administrative Agent shall have received a certificate from the chief financial officer of the Borrower in form and substance satisfactory to the Administrative Agent certifying that after giving effect to the Transactions to occur on the Closing Date, the Borrower and its Subsidiaries, on a consolidated basis, are solvent.

xx. All requisite Governmental Authorities and third parties shall have approved or consented to the Transactions and the other transactions contemplated hereby to the extent required, all applicable appeal periods shall have expired and there shall not be any pending or, to the knowledge of the Borrower, threatened litigation, governmental, administrative or judicial action that could reasonably be expected to restrain, prevent or impose burdensome conditions on the Transactions or the other transactions contemplated hereby.

xxi. At least five Business Days prior to the Closing Date, the Lenders shall have received, to the extent previously requested, all documentation and other information required by regulatory authorities under applicable “know your customer” and anti-money laundering rules and regulations, including the USA PATRIOT Act.

 

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xxii. The Administrative Agent shall have received true, correct and complete copies of (i) the Holdings Notes Documents, which shall be in form and substance reasonably satisfactory to the Administrative Agent and each of the conditions precedent to the effectiveness thereof shall have been satisfied or waived in writing in accordance with the terms thereof. Holdings shall have received and contributed to the Borrower, or substantially contemporaneously with the initial funding of the Loans on the Closing Date shall receive and contribute to the Borrower, net cash proceeds of not less than $375,000,000 from the issuance of the Holdings Notes.

5.

Affirmative Covenants

The Borrower covenants and agrees with each Lender that until the Commitments have been terminated and the principal of and interest on each Loan, all Fees and all other expenses or amounts payable under any Loan Document shall have been paid in full, unless the Required Lenders shall otherwise consent in writing, the Borrower will, and will cause each of the Subsidiaries to:

A. Existence; Compliance with Laws; Businesses. i. Do or cause to be done all things necessary to preserve, renew and keep in full force and effect its legal existence, except as otherwise expressly permitted under Section 6.05.

ii. Do or cause to be done all things necessary to obtain, preserve, renew, extend and keep in full force and effect the rights, licenses, permits, franchises, authorizations, patents, copyrights, trademarks and trade names material to the conduct of its business; maintain and operate such business in substantially the manner in which it is presently conducted and operated; and comply in all material respects with all applicable laws, rules, regulations and decrees and orders of any Governmental Authority, whether now in effect or hereafter enacted except in each case under this Section 5.01(b), where the failure to do so would not reasonably be expected to have a Material Adverse Effect.

B. Operation and Maintenance of Properties. i. Operate its Oil and Gas Properties and other material properties, or cause such Oil and Gas Properties and other material properties to be operated, in a careful and efficient manner in accordance with the practices of the industry and in compliance with all applicable contracts and agreements, all applicable Environmental Laws, and all applicable laws, rules and regulations of every relevant Governmental Authority which regulates the development and operation of its Oil and Gas Properties and the production and sale of Hydrocarbons and other minerals therefrom, including without limitation, the rules and regulations promulgated by the BOEM/BSEE applicable to the plugging and abandonment of the Loan Parties’ Oil and Gas Properties except, in each case, where the failure to do so could not reasonably be expected to have a Material Adverse Effect.

ii. Unless such property is subject to a sale, assignment or disposition permitted under Section 6.05, keep and maintain all property used or to be used in the conduct of its business in good working order and condition, ordinary wear and tear excepted, except where the failure to do so could not reasonably be expected to have a Material Adverse Effect.

 

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iii. Promptly pay and discharge, or make reasonable and customary efforts to cause to be paid and discharged, all delay rentals, royalties, expenses and indebtedness accruing under the leases or other agreements affecting or pertaining to its Oil and Gas Properties and do all other things necessary to keep unimpaired its rights with respect thereto and prevent any forfeiture thereof or default thereunder, except where the failure to do so could not reasonably be expected to result in a Material Adverse Effect.

iv. Promptly perform or make reasonable and customary efforts to cause to be performed, in accordance with customary industry standards, the obligations required by the assignments, deeds, leases, sub-leases, contracts and agreements affecting its interests in its Oil and Gas Properties and other material properties, except, in each case, where the failure to do so could not reasonably be expected to have a Material Adverse Effect.

To the extent the Borrower or one of its Subsidiaries is not the operator of any property, the Borrower shall use commercially reasonable efforts to cause the operator to comply with this Section 5.02, but failure of the operator so to comply will not constitute a Default or an Event of Default hereunder.

C. Insurance. i. Keep its insurable properties adequately insured at all times by financially sound and reputable insurers; maintain such other insurance, to such extent and against such risks, including fire and other risks insured against by extended coverage, as is customary with companies in the same or similar businesses operating in the same or similar locations, including public liability insurance against claims for personal injury or death or property damage occurring upon, in, about or in connection with the use of any properties owned, occupied or controlled by it; maintain insurance against windstorm damage to the extent the same can be obtained and maintained on commercially reasonable terms and maintain such other insurance as may be required by law.

ii. Cause all such policies covering any Collateral to be endorsed or otherwise amended to include a customary lender’s loss payable endorsement, in form and substance satisfactory to the Administrative Agent and the Collateral Agent. To the extent that the insurer will agree to do so, such policies will also provide that the insurer will endeavor to give at least thirty (30) days prior notice of any cancellation to the Administrative Agent and the Collateral Agent.

iii. Notify the Administrative Agent and the Collateral Agent promptly whenever any separate insurance concurrent in form or contributing in the event of loss with that required to be maintained under this Section 5.03 is taken out by any Loan Party; and promptly deliver to the Administrative Agent and the Collateral Agent a duplicate original copy of such policy or policies, or an insurance certificate with respect thereto.

D. Obligations and Taxes. Except as reflected on Schedule 3.14, pay its Indebtedness and other obligations promptly and in accordance with their terms and pay and discharge promptly when due all Taxes, remittance obligations, assessments and governmental charges or levies imposed upon it or upon its income or profits or in respect of its property, before the same shall become delinquent or in default, except where (a) the validity or amount thereof is being contested in good faith by appropriate proceedings and the Borrower or the

 

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applicable Subsidiary has set aside on its books adequate reserves with respect thereto in accordance with GAAP or (b) the failure to make such payment could not reasonably be expected to result in a Material Adverse Effect or result in the imposition of a Lien on Collateral not permitted hereunder.

E. Financial Statements, Reports, etc. In the case of the Borrower, furnish to the Administrative Agent, which shall furnish to each Lender:

i. within one hundred twenty (120) days after the end of each fiscal year, its consolidated balance sheet and related statements of income, stockholders’ equity and cash flows showing the financial condition of the Borrower and its Consolidated Subsidiaries as of the close of such fiscal year and the results of its operations and the operations of such Subsidiaries during such year, together with comparative figures for the immediately preceding fiscal year, all audited by Hein & Associates LLP or other independent public accountants of recognized national standing reasonably acceptable to the Administrative Agent and accompanied by an opinion of such accountants (which opinion shall be without a “going concern” or like qualification or exception or explanatory note and without any qualification or exception as to the scope of such audit) to the effect that such consolidated financial statements fairly present in all material respects the financial condition and results of operations of the Borrower and its Consolidated Subsidiaries on a consolidated basis in accordance with GAAP consistently applied, together with a customary “management’s discussion and analysis”;

ii. within sixty (60) days after the end of each of the first three fiscal quarters of each fiscal year, its consolidated balance sheet and related statements of income, stockholders’ equity and cash flows showing the financial condition of the Borrower and its Consolidated Subsidiaries as of the close of such fiscal quarter and the results of its operations and the operations of such Subsidiaries during such fiscal quarter and the then elapsed portion of the fiscal year, and, other than with respect to quarterly reports during the remainder of the first fiscal year after the Closing Date, comparative figures for the same periods in the immediately preceding fiscal year, all certified by one of its Financial Officers as fairly presenting in all material respects the financial condition and results of operations of the Borrower and its Consolidated Subsidiaries on a consolidated basis in accordance with GAAP consistently applied, subject to the absence of footnotes and normal year-end audit adjustments;

iii. concurrently with any delivery of financial statements under paragraph (a) or (b) above, a certificate of a Financial Officer of the Borrower in the form of Exhibit D (i) certifying that no Event of Default or Default has occurred or, if such an Event of Default or Default has occurred, specifying the nature and extent thereof and any corrective action taken or proposed to be taken with respect thereto and (ii) setting forth computations in reasonable detail satisfactory to the Administrative Agent demonstrating compliance with the covenant contained in Section 6.12;

iv. concurrently with any delivery of financial statements under paragraph (a) or (b) above, a certificate of a Financial Officer of the Borrower in form and substance reasonably satisfactory to the Administrative Agent setting forth as of a recent date, a true and complete list of all Hedging Agreements of the Borrower and each Subsidiary, the material terms thereof (including the type, term, effective date, termination date and notional amounts or volumes), any

 

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new credit support agreements relating thereto (other than Loan Documents), any margin required or supplied under any credit support document, and the counterparty to each such agreement;

v. concurrently with any delivery of financial statements under clause (b) above and concurrently with the delivery of the Reserve Report pursuant to Section 5.15 (unless requested more frequently by the Administrative Agent), production and operating reports (the same to include information as to volumes produced and sold and the amount received by the Loan Parties) in respect of the Oil and Gas Properties of the Loan Parties given value in the most recently delivered Reserve Report;

vi. as soon as available and in any event no later than 90 days after the commencement of each fiscal year of the Borrower a monthly cash flow budget and development plan for such fiscal year prepared by a Financial Officer of the Borrower detailing therein, inter alia, projected monthly production volumes and gross revenues from the Proved Reserves, general and administrative costs, operating costs, royalties and other burdens, commodity price assumptions, Taxes and budgeted Capital Expenditures together with a forecasted operating budget of the Borrower for the following year detailed on a monthly basis;

vii. promptly after the same become publicly available, copies of all periodic and other reports, proxy statements and other materials filed by the Borrower or any Subsidiary with the SEC or with any national securities exchange, or distributed to its shareholders, as the case may be;

viii. promptly after the receipt thereof by the Borrower or any of the Subsidiaries, a copy of any “management letter” received by any such Person from its certified public accountants and the management’s response thereto;

ix. promptly after the request by any Lender, all documentation and other information that such Lender reasonably requests in order to comply with its ongoing obligations under applicable “know your customer” and anti-money laundering rules and regulations, including the USA PATRIOT Act;

x. promptly after the request by the Administrative Agent or any Lender, copies of (i) any documents described in Section 101(k)(1) of ERISA that the Borrower or any of its ERISA Affiliates may request with respect to any Multiemployer Plan and (ii) any notices described in Section 101(l)(1) of ERISA that the Borrower or any of its ERISA Affiliates may request with respect to any Multiemployer Plan;

xi. [reserved];

xii. promptly, from time to time, upon the Administrative Agent’s reasonable request, (i) other information that is delivered to any Person pursuant to the terms of any indenture, loan or other credit or other similar agreement with respect to Material Indebtedness, in each case, solely to such Person in its capacity as an agent or a lender thereunder, in the same form as so delivered and (ii) such other information regarding the operations, business affairs and financial condition of the Borrower or any Subsidiary, or compliance with the terms of any Loan Document; and

 

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xiii. beginning with the quarter ending September 30, 2014, concurrently with any delivery of financial statements under paragraphs (a) and (b) above, notice of the date and time of a conference call with Lenders and the Administrative Agent to discuss such financial information, which conference call the Borrower shall host not later than ten (10) Business Days (or such other date as the Borrower and the Administrative Agent may agree) after such delivery.

F. Litigation and Other Notices. Furnish to the Administrative Agent and each Lender prompt, but in any event, within three (3) Business Days’, written notice of the following:

i. any Event of Default or Default, specifying the nature and extent thereof and the corrective action (if any) taken or proposed to be taken with respect thereto;

ii. the filing or commencement of, or receipt of notice of intention of any Person to file or commence, any action, suit, investigation or proceeding, whether at law or in equity or by or before any Governmental Authority, against the Borrower or any Affiliate thereof that could reasonably be expected to result in a Material Adverse Effect;

iii. the occurrence of any ERISA Event that, alone or together with any other ERISA Events that have occurred, could reasonably be expected to result in liability of the Borrower and the Subsidiaries in an aggregate amount exceeding $10,000,000; and

iv. the occurrence of any Casualty Event or the commencement of any action or proceeding that could reasonably be expected to result in a Casualty Event; and

v. any development that has resulted in a Material Adverse Effect.

G. Information Regarding Collateral. Furnish to the Administrative Agent and the Collateral Agent at least fifteen days’ (or such shorter period of time as may be reasonably agreed in writing by the Administrative Agent) prior written notice of any change (i) in any Loan Party’s corporate name, (ii) in the jurisdiction of organization or formation of any Loan Party, (iii) in any Loan Party’s identity or corporate structure or (iv) in any Loan Party’s Federal Taxpayer Identification Number. The Borrower agrees not to effect or permit any change referred to in the preceding sentence unless prior notice has been provided to the Administrative Agent and the Collateral Agent. The Borrower also agrees promptly to notify the Administrative Agent if any material portion of the Collateral is damaged or destroyed.

H. Maintaining Records; Access to Properties and Inspections. i. Keep proper books of record and account in which entries fairly presented in all material respects and in accordance with GAAP consistently applied are made of all dealings and transactions in relation to its business and activities. Each Loan Party will, and will cause each of its subsidiaries to, permit any representatives designated by the Administrative Agent, upon reasonable prior notice, to visit and inspect the financial records and the properties of such Person at reasonable times and as often as reasonably requested and to make extracts from and copies of such financial records, and permit any representatives designated by the Administrative Agent to discuss the affairs, finances and condition of such Person with the officers thereof and independent accountants therefor.

 

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ii. Beginning with the quarter ending September 30, 2014, the Borrower will hold a conference call for all Lenders and the Administrative Agent at a mutually agreeable time to discuss such financial information within ten (10) Business Days (or such other date as the Borrower and the Administrative Agent may agree) following distribution of the financial information referred to in Sections 5.05(a) and 5.05(b).

I. Use of Proceeds. Use the proceeds of the Loans only for the purposes specified in the introductory statement to this Agreement.

J. Employee Benefits. (a) Comply in all material respects with the applicable provisions of ERISA and the Code and (b) furnish to the Administrative Agent as soon as possible after, and in any event within ten days after any responsible officer of the Borrower or any ERISA Affiliate knows or has reason to know that, any ERISA Event has occurred that, alone or together with any other ERISA Event could reasonably be expected to result in liability of, the Borrower or any ERISA Affiliate in an aggregate amount exceeding $10,000,000, a statement of a Financial Officer of the Borrower setting forth details as to such ERISA Event and the action, if any, that the Borrower proposes to take with respect thereto.

K. [Reserved].

L. Environmental Matters.

(a) The Borrower shall at its sole expense: (i) comply, and shall cause its properties and operations and each Subsidiary and its properties and operations to comply, with applicable Environmental Laws, the breach of which, individually or in the aggregate, could reasonably be expected to have a Material Adverse Effect; (ii) not Release or threaten to Release, and shall cause each Subsidiary not to Release or threaten to Release, any Hazardous Material on, under, about or from any of the Borrower’s or the Subsidiaries’ properties or any other offsite location to the extent related to the Borrower’s or any of the Subsidiaries’ operations, the Release or threatened Release of which, individually or in the aggregate, could reasonably be expected to have a Material Adverse Effect; (iii) timely obtain or file, and shall cause each Subsidiary to timely obtain or file, all environmental permits to be obtained or filed in connection with the operation or use of the Borrower’s or the Subsidiaries’ properties, which failure to obtain or file, individually or in the aggregate, could reasonably be expected to have a Material Adverse Effect; and (iv) promptly commence and diligently prosecute to completion, and shall cause each Subsidiary to promptly commence and diligently prosecute to completion, any assessment, evaluation, investigation, monitoring, containment, cleanup, removal, repair, restoration, remediation or other remedial obligations (collectively, the “Remedial Work”) in the event such Remedial Work is required under applicable Environmental Laws because of or in connection with the Release or threatened Release of Hazardous Material on, under, about or from any of the Borrower’s or the Subsidiaries’ properties or otherwise in connection with their respective operations, which failure to commence and diligently prosecute to completion, individually or in the aggregate, could reasonably be expected to have a Material Adverse Effect.

(b) The Borrower will promptly, but in no event later than five (5) days of the occurrence of a triggering event, notify the Administrative Agent and the Lenders in writing of any action or investigation initiated, commenced or threatened in writing by any Governmental

 

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Authority or any demand or lawsuit initiated, commenced or threatened in writing by any landowner or other third party against the Borrower or any of the Subsidiaries or their respective properties of which the Borrower has knowledge in connection with any Environmental Laws if the Borrower could reasonably anticipate that such action will result in liability in excess of $10,000,000, not fully covered by insurance, subject to normal deductibles.

(c) The Borrower shall provide any environmental assessments, audits and tests obtained by the Borrower or any Subsidiary in connection with any future acquisitions of Oil and Gas Properties or other properties to the Administrative Agent and the Lenders.

(d) To the extent the Borrower is not the operator of any Oil and Gas Property, the Borrower shall use reasonable efforts to cause the operator to comply with this Section 5.12.

M. Further Assurances. Execute any and all further documents, financing statements, agreements and instruments, and take all further action (including filing Uniform Commercial Code and other financing statements, mortgages and deeds of trust) that may be required under applicable law, or that the Administrative Agent or the Collateral Agent may reasonably request, in order to effectuate the transactions contemplated by the Loan Documents and in order to grant, preserve, protect and perfect the validity and the priority of the security interests created or intended to be created by the Security Documents to the extent required under this Agreement or any Security Document.

N. Additional Collateral; Additional Guarantors.

i. On or before the delivery to the Administrative Agent and the Lenders of each Reserve Report required by Section 5.15(a), the Borrower will review the Reserve Report and the list of current Mortgaged Properties (as described in Section 5.15(d)) to ascertain whether the Mortgaged Properties represent at least 80% of the PV-10 Value as reflected in the most recently delivered Reserve Report after giving effect to exploration and production activities, acquisitions, dispositions and production. In the event that the Mortgaged Properties do not represent at least 80% of such PV-10 Value, then the Borrower shall, and shall cause the Subsidiary Guarantors to, within thirty (30) days of delivery of the certificate required under Section 5.15(d) (or such later date as the Collateral Agent may agree), execute and deliver a Mortgage or a supplement to a Mortgage granting the Collateral Agent as security for the Obligations a perfected Lien of the type and priority described in such Mortgage on additional Oil and Gas Properties not already subject to a Lien of the Security Documents such that after giving effect thereto, the Mortgaged Properties will represent at least 80% of such PV-10 Value. All such Liens will be created and perfected by and in accordance with the provisions of deeds of trust, security agreements and financing statements or other Security Documents, all in form and substance reasonably satisfactory to the Collateral Agent and in sufficient executed (and acknowledged where necessary or appropriate) counterparts for recording purposes.

ii. [Reserved].

iii. In addition, from time to time, the Borrower will, at its cost and expense, secure the Obligations by pledging or creating, or causing to be pledged or created, perfected security interests with respect to such of its assets and properties as the Administrative Agent or the

 

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Required Lenders shall designate within thirty (30) days of such designation (or such later date as the Collateral Agent may agree (it being understood that it is the intent of the parties that the Obligations shall be secured by substantially all the assets of the Borrower, the Domestic Subsidiaries and, to the extent no adverse tax consequences to the Borrower would result therefrom (including any such adverse consequences arising under Section 951(a) of the Code as a result of any Foreign Subsidiary being classified as a controlled foreign corporation under Section 957(a) of the Code), the Foreign Subsidiaries (including oil and gas leases and other real and other properties acquired subsequent to the Closing Date)); provided that no Loan Party (i) shall be required to grant a security interest in any asset or property as to which the Administrative Agent reasonably determines, in consultation with the Borrower, that the cost of obtaining or perfecting a security interest therein is excessive in relation to the benefit to the Secured Parties of the security to be afforded thereby, (ii) shall be required to grant a security interest in any deposit account or any other asset or property that is expressly excluded from Collateral in the Security Documents, (iii) shall be required to perfect a security interest in any Collateral that is not required by the terms of the Security Documents to be perfected, and (iv) shall be required to grant a security interest or mortgage lien on any Oil and Gas Properties to the extent not required to comply with Section 5.14(a) above. Such security interests and Liens will be created under the Security Documents and other security agreements, mortgages, deeds of trust and other instruments and documents in form and substance reasonably satisfactory to the Collateral Agent, and the Borrower shall deliver or cause to be delivered to the Collateral Agent all such instruments and documents (including legal opinions and lien searches) as the Collateral Agent shall reasonably request within such thirty-day period to evidence compliance with this Section.

iv. The Borrower will cause (i) each subsequently acquired or organized Domestic Subsidiary and, to the extent no adverse tax consequences to the Borrower would result therefrom (including any such adverse consequences arising under Section 951(a) of the Code as a result of any Foreign Subsidiary being classified as a controlled foreign corporation under Section 957(a) of the Code), Foreign Subsidiary, to become a Loan Party by executing the Guarantee and Collateral Agreement (or a supplement thereto, in form and substance reasonably acceptable to the Administrative Agent) and each applicable Security Document in favor of the Collateral Agent within thirty (30) days after the acquisition or organization thereof (or such later date as the Collateral Agent may agree) and (ii) any Subsidiary which Guarantees or otherwise provides direct credit support for any other Indebtedness of the Borrower to contemporaneously become a Subsidiary Guarantor hereunder.

O. Reserve Reports.

i. On or before April 1st and October 1st of each year, commencing October 1, 2014, the Borrower shall furnish to the Administrative Agent and the Lenders a Reserve Report evaluating the Oil and Gas Properties of the Borrower and the Subsidiary Guarantors as of the immediately preceding January 1st (each, a “January 1 Reserve Report”) and July 1st, respectively (each, a “July 1 Reserve Report”), such Reserve Report to have been prepared in accordance with the procedures used in the immediately preceding January 1 Reserve Report (or, in the case of the first Reserve Report delivered pursuant to this Section 5.15(a), the Initial Reserve Report). The January 1 Reserve Report for each year shall be prepared by one or more Approved Petroleum Engineers, and the July 1 Reserve Report for each year may be prepared by

 

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one or more Approved Petroleum Engineers or internally under the supervision of the chief engineer of the Borrower in accordance with the procedures used in the immediately preceding January 1 Reserve Report.

ii. [Reserved].

iii. Each Reserve Report may be supplemented by all such other internal information as the Borrower or the Administrative Agent, acting reasonably, may request or deem appropriate, including without limitation sufficient internally prepared information to permit the Administrative Agent’s engineering consultants to prepare economic engineering evaluations covering the Oil and Gas Properties.

iv. With the delivery of each Reserve Report (including the Initial Reserve Report), the Borrower shall be deemed to certify that in all material respects: (i) there are no statements or conclusions in the Reserve Report which are based upon or include materially misleading information or fail to take into account material information regarding the matters reported therein, it being understood that projections concerning volumes attributable to the Oil and Gas Properties of the Borrower and the Subsidiary Guarantors and production and cost estimates contained in the Reserve Report are necessarily based upon professional opinions, estimates and projections and that the Borrower does not warrant that such opinions, estimates and projections will ultimately prove to have been accurate, (ii) except as could not reasonably be expected to have a Material Adverse Effect, the Borrower or the Subsidiary Guarantors have good and defensible title to the Oil and Gas Properties evaluated in such Reserve Report and such properties are free of all Liens except for Liens permitted by Section 6.02 and (iii) except as set forth in such Reserve Report or in a writing delivered in connection therewith, on a net basis there are no gas imbalances, take or pay or other prepayments with respect to its Oil and Gas Properties evaluated in such Reserve Report that would otherwise require disclosure on Schedule 3.26. With each such Reserve Report, the Borrower will also deliver a schedule of the Oil and Gas Properties evaluated by such Reserve Report that are Mortgaged Properties and demonstrating the percentage of the PV-10 Value that the value of such Mortgaged Properties represent in compliance with Section 5.14(a).

P. Title Information.

i. On or before the delivery to the Administrative Agent and the Lenders of each Reserve Report required by Section 5.15(a), the Borrower will deliver title information in form and substance reasonably acceptable to the Administrative Agent covering enough of the Oil and Gas Properties evaluated by such Reserve Report that were not included in the immediately preceding Reserve Report or for which no title information had been previously delivered to the Administrative Agent, so that the Administrative Agent shall have received together with title information previously delivered to the Administrative Agent, satisfactory title information on at least 80% of the PV-10 Value as reflected in the most recently delivered Reserve Report.

ii. If the Borrower has provided title information for additional properties under Section 5.16(a), the Borrower shall, within 60 days of notice from the Administrative Agent that title defects or exceptions exist with respect to such additional properties, either (i) cure any such title defects or exceptions (including defects or exceptions as to priority) which are not permitted

 

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by Section 6.02 raised by such information, (ii) substitute acceptable Mortgaged Properties with no title defects or exceptions except for Excepted Liens having an equivalent value or (iii) deliver title information in form and substance acceptable to the Administrative Agent so that the Administrative Agent shall have received, together with title information previously delivered to the Administrative Agent, satisfactory title information on at least 80% of the PV-10 Value as reflected in the most recently delivered Reserve Report.

Q. Hedging Agreements. Not later than 45 days after the Closing Date, the Loan Parties shall enter into Hedging Agreements with one or more Approved Counterparties that are for not less than 40% of the Borrower’s and its Subsidiaries’ aggregate Forecasted Proved Reserve Production anticipated to be sold in the ordinary course of such Persons’ business for an initial period of not less than 24 months and for rolling 24-month periods thereafter.

6.

Negative Covenants

The Borrower covenants and agrees with each Lender that, until the Commitments have been terminated and the principal of and interest on each Loan, all Fees and all other expenses or amounts payable under any Loan Document have been paid in full, unless the Required Lenders shall otherwise consent in writing, the Borrower will not, nor will it cause or permit any of its Subsidiaries to:

A. Indebtedness. Incur, create, assume or permit to exist any Indebtedness, except:

i. Indebtedness (including unsecured intercompany Indebtedness) existing on the date hereof and set forth in Schedule 6.01 and any Permitted Refinancing Indebtedness in respect thereof;

ii. Indebtedness created hereunder and under the other Loan Documents;

iii. Guarantees by the Borrower and the Subsidiaries in respect of Indebtedness otherwise permitted hereunder of the Borrower or any Subsidiary to the extent constituting an Investment permitted under Section 6.04; provided that (A) if the Indebtedness being Guaranteed is subordinated to the Obligations, such Guarantee shall be subordinated to the Guarantee of the Obligations on terms at least as favorable to the Lenders (in the reasonable good faith determination of the Borrower) as those contained in the subordination of such Indebtedness and (B) a Loan Party may not Guarantee Indebtedness of a Subsidiary that is not a Loan Party unless such Loan Party could have incurred such Indebtedness or such Guarantee is subordinated to the Obligations on the terms set forth in the Guarantee and Collateral Agreement;

iv. unsecured intercompany Indebtedness to the extent permitted by Section 6.04 so long as all such Indebtedness of any Loan Party to a Person that is not a Loan Party is subordinated to the Obligations on terms set forth in the Guarantee and Collateral Agreement; provided, that (i) any subsequent issuance or transfer of Equity Interests that results in any such Indebtedness being held by a Person other than a Loan Party and (ii) any sale or other transfer of any such Indebtedness to a Person that is not a Loan Party, will be deemed, in each case, to constitute an incurrence of such Indebtedness that was not permitted by this Section 6.01(d);

 

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v. (i) Capital Lease Obligations and Indebtedness of the Borrower or any Subsidiary incurred to finance the acquisition, construction or improvement of any fixed asset, capital assets or equipment; provided that such Indebtedness is incurred prior to or within 270 days after such acquisition or the completion of such construction or improvement and (ii) any Permitted Refinancing Indebtedness in respect thereof; provided that the aggregate principal amount of Indebtedness permitted by this Section 6.01(e) shall not exceed $25,000,000 at any time outstanding;

vi. Indebtedness in respect of self-insurance obligations or bid, plugging and abandonment, appeal, reimbursement, performance, surety and similar bonds, letters of credit and completion guarantees provided by the Borrower or any Subsidiary in the ordinary course of business or obligations and workers’ compensation claims in the ordinary course of business;

vii. endorsements of negotiable instruments for collection in the ordinary course of business;

viii. Indebtedness arising under Cash Management Agreements in respect of Cash Management Services with any financial institution in which the Borrower or any of its Subsidiaries maintains a deposit account;

ix. any obligation arising from agreements of the Borrower or any Subsidiary providing for indemnification, adjustment of purchase price, earn outs, or similar obligations, in each case, incurred or assumed in connection with the disposition or acquisition of any business, assets or Equity Interest of a Subsidiary in a transaction permitted under this Agreement;

x. Indebtedness of the Borrower or any Subsidiary assumed in connection with a Permitted Acquisition; provided that (A) such Indebtedness exists at the time of such Permitted Acquisition and is not created in contemplation of or in connection with such Permitted Acquisition, (B) immediately before and after the consummation of such Permitted Acquisition, no Default or Event of Default shall have occurred and be continuing and (C) after giving effect to such Permitted Acquisition, the Leverage Ratio as of the end of the most recently ended four-fiscal quarter period of the Borrower for which financial statements have been delivered pursuant to Section 5.05(a) or (b), determined on a pro forma basis, would not exceed the Leverage Ratio as of the end of such four-fiscal quarter period;

xi. [Reserved];

xii. [Reserved];

xiii. Indebtedness in respect of Hedging Agreements designed to hedge against the Borrower’s or any Subsidiary’s exposure to interest rates, foreign exchange rates or commodities pricing risks incurred in the ordinary course of business and not for speculative purposes;

xiv. Indebtedness owing in connection with the financing of insurance premiums in the ordinary course of business;

xv. Indebtedness in the form of obligations for the deferred purchase price of property or services incurred in the ordinary course of business which are not yet due and payable or are being contested in good faith by appropriate proceedings and for which adequate reserves in accordance with GAAP have been established;

 

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xvi. Indebtedness in the form of a Guarantee by any Loan Party of any obligation (whether payment, performance or otherwise) of any other Loan Party so long as such obligation is otherwise permitted under this Agreement; and

xvii. other unsecured Indebtedness of the Borrower or the Subsidiaries in an aggregate principal amount not to exceed $25,000,000 at any time outstanding.

Notwithstanding anything herein to the contrary, and for the avoidance of doubt, neither the Borrower nor any Subsidiary Guarantor will incur any Guarantee in respect of the obligations of Holdings under the Holdings Notes Documents or any refinancings of the Holdings Notes.

B. Liens. Create, incur, assume or permit to exist any Lien on any property or assets (including Equity Interests or other securities of any Subsidiary) now owned or hereafter acquired by it or on any income or revenues or rights in respect of any thereof, except:

i. Excepted Liens;

ii. Liens on property or assets of the Borrower and its Subsidiaries existing on the date hereof and set forth in Schedule 6.02 (together with any additional property or assets of the Borrower or any Subsidiary constituting (A) after-acquired property that is affixed or incorporated into the property covered by such Lien or (B) proceeds and products thereof); provided that (i) such Liens shall secure only those obligations which they secure on the date hereof and extensions, renewals and replacements thereof permitted hereunder and (ii) such Liens do not extend to any other property or assets of the Borrower or its Subsidiaries;

iii. any Lien (i) created under the Loan Documents or (ii) securing Obligations of the type set forth in clause (c) of the definition thereof; provided that, in the case of this clause (ii), any such Lien does not extend to any property or assets of the Borrower or any Subsidiary other than such property and assets that constitute Collateral under the Loan Documents;

iv. [Reserved];

v. any Lien existing on any property or asset prior to the acquisition thereof by the Borrower or any Subsidiary or existing on any property or assets of any Person that becomes a Subsidiary after the date hereof prior to the time such Person becomes a Subsidiary, as the case may be; provided that (i) such Lien is not created in contemplation of or in connection with such acquisition or such Person becoming a Subsidiary, (ii) such Lien does not apply to any other property or assets of the Borrower or any Subsidiary (other than the proceeds or products thereof and other than improvements and after-acquired property subjected to a Lien securing Indebtedness and other obligations incurred prior to such time and which Indebtedness and other obligations are permitted hereunder that require, pursuant to their terms at such time, a pledge of after-acquired property, it being understood that such requirement shall not be permitted to apply to any property to which such requirement would not have applied but for such acquisition), and (iii) such Lien secures only those obligations which it secures on the date of such acquisition or the date such Person becomes a Subsidiary, as the case may be;

 

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vi. Liens securing Indebtedness incurred under Section 6.01(e); provided that (i) such Liens are incurred, and the Indebtedness secured thereby is created, within 270 days after such acquisition, construction or improvement, and (ii) such security interests do not apply to any other property or assets (other than accessions to such property or assets) of the Borrower or any Subsidiary;

vii. Consultant Overrides, the Petro Capital Overrides, and the Guggenheim Overrides;

viii. licenses of intellectual property granted by a Loan Party in the ordinary course of business and not interfering in any martial respect with the ordinary conduct of business for such Loan Party; and

ix. other Liens securing obligations not to exceed $25,000,000 in the aggregate.

C. Sale and Lease-Back Transactions. Enter into any arrangement, directly or indirectly, with any Person whereby it shall sell or transfer any property, real or personal, used or useful in its business, whether now owned or hereafter acquired, and thereafter rent or lease such property or other property which it intends to use for substantially the same purpose or purposes as the property being sold or transferred unless (i) the sale or transfer of such property is permitted by Section 6.05 and (ii) any Capital Lease Obligations or Liens arising in connection therewith are permitted by Sections 6.01 and 6.02, as the case may be.

D. Investments, Loans and Advances. Make or permit to remain outstanding any Investments in or to any Person, except:

i. Purchases of the Equity Interests of, or capital contributions to, any Loan Party;

ii. Investments that were Permitted Investments when made and, subject to the limits in Section 6.17, Permitted Acquisitions;

iii. Investments (i) by the Borrower or any Subsidiary in the Borrower or any Subsidiary that is a Loan Party, (ii) by any Subsidiary that is not a Loan Party in any other Subsidiary that is also not a Loan Party, and (iii) by the Borrower or any Subsidiary in any Subsidiary that is not a Loan Party; provided that the aggregate amount of such Investments in Subsidiaries that are not Loan Parties shall not exceed $10,000,000; provided that any such Investments consisting of loans and advances shall be unsecured and, where loaned or advanced by a Subsidiary that is not a Loan Party to a Loan Party, subordinated to the Obligations on terms set forth in the Guarantee and Collateral Agreement; and Guarantees of any Indebtedness of any other Loan Party permitted to be incurred pursuant to Section 6.01;

iv. Investments (i) consisting of extensions of credit in the nature of accounts receivable or notes receivable arising from the grant of trade credit in the ordinary course of business or (ii) received in connection with the bankruptcy or reorganization of, or settlement of delinquent accounts and disputes with, customers and suppliers, in each case in the ordinary course of business;

 

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v. loans and advances in the ordinary course of business to the officers, directors and employees of any Loan Party so long as the aggregate principal amount thereof at any time outstanding (determined without regard to any write-downs or write-offs of such loans and advances) shall not exceed $5,000,000 in the aggregate at any time outstanding;

vi. Hedging Agreements entered into in the ordinary course of business and not for speculative purposes and otherwise permitted under this Agreement;

vii. Investments arising out of the receipt by the Borrower or any Subsidiary of non-cash consideration for the sale of assets permitted under Section 6.05;

viii. Investments of a Subsidiary acquired after the Closing Date or of a Person merged into any Loan Party in accordance with Section 6.05 after the Closing Date to the extent that such Investments were not made in contemplation of or in connection with such acquisition, merger or consolidation and were in existence on the date of such acquisition, merger or consolidation;

ix. creation of any additional Subsidiaries of any Loan Party in compliance with Section 5.14;

x. increases in net revenue interests on any Oil and Gas Properties resulting from repurchases of the Guggenheim Overrides or the Petro Capital Overrides; and

xi. additional Investments of the Borrower or any Subsidiary so long as the aggregate amount of all such Investments (determined without regard to any write-downs or write-offs of such investments, loans and advances) does not exceed $25,000,000.

E. Mergers, Consolidations, Dispositions and Acquisitions. Merge into or consolidate with any other Person, or permit any other Person to merge into or consolidate with it, or Dispose of (in one transaction or in a series of transactions) all or part of its assets (whether now owned or hereafter acquired), or issue any Equity Interest in any Subsidiary, or purchase, lease or otherwise acquire (in one transaction or a series of transactions) all or any substantial part of the assets of any other Person, except that this Section will not prohibit:

i. Permitted Acquisitions;

ii. the sale of inventory (including Hydrocarbons sold as produced) or the purchase and sale of supplies, materials, equipment, contract rights or licenses or leases of intellectual property, in each case in the ordinary course of business by the Borrower or any Subsidiary;

iii. the Disposition of surplus, obsolete or worn out equipment or other property in the ordinary course of business by the Borrower or any Subsidiary;

iv. (i) the merger or consolidation or Disposition of all of substantially all its assets of any Subsidiary into the Borrower in a transaction in which the Borrower is the surviving corporation, (ii) the merger or consolidation or Disposition of all of substantially all its assets of any Subsidiary into or with any Subsidiary Guarantor in a transaction in which the surviving or resulting entity is a Subsidiary Guarantor and (iii) the merger or consolidation or Disposition of all or substantially all of its assets of any Subsidiary that is not a Loan Party into any other Subsidiary that is not a Loan Party;

 

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v. the Disposition of (i) Permitted Investments permitted by Section 6.04(b) in the ordinary course of business and (ii) Investments permitted by Section 6.04(d)(ii) and (g);

vi. the acquisition by the Borrower or any Subsidiary of interests in Oil and Gas Properties (and Subsidiaries owning Oil and Gas Properties) and gas gathering systems related thereto; and acquisitions and Dispositions by the Borrower or any Subsidiary of property pursuant to farm-out, farm-in, joint operating and area of mutual interest agreements, in each case, within the geographic boundaries of the United States of America and subject to the jurisdiction of the United States and which are usual and customary in the oil and gas exploration and production business;

vii. Dispositions of claims against customers, working interest owners, other industry partners or any other Person in connection with workouts or bankruptcy, insolvency or other similar proceedings with respect thereto or collection or compromises of accounts receivable;

viii. Dispositions of property to the extent that (i) such property is exchanged for credit against the purchase price of similar replacement property or (ii) the proceeds of such Disposition are promptly applied to the purchase price of such replacement property;

ix. Dispositions of property to the Borrower or to a Subsidiary; provided that if the transferor of such property is a Loan Party or the Borrower, the transferee thereof must either be the Borrower or a Loan Party;

x. leases, licenses, subleases or sublicenses granted to others in the ordinary course of business which do not interfere in any material respect with the business of the Borrower or any Subsidiary;

xi. Dispositions of Investments in joint ventures to the extent required by, or made pursuant to customary buy/sell arrangements between, the joint venture parties set forth in joint venture arrangements and similar binding arrangements;

xii. Dispositions of funds collected for the beneficial interest of, or of the interests owned by, royalty, overriding royalty or working interest owners;

xiii. [Reserved;]

xiv. [Reserved;]

xv. Dispositions pursuant to and in accordance with the terms of the “Halcón Purchase Agreement” and the “Halcón AMI 2 Agreement”, as each such term is defined in the Constellation Agreement;

xvi. transfers of Oil and Gas Properties in exchange for Oil and Gas Properties of equal or greater value (as determined by the Borrower); and

 

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xvii. Asset Sales by the Borrower or any Subsidiary not otherwise permitted by this Section 6.05; provided (i) no Event of Default then exists or would result therefrom, (ii) with respect to any such Asset Sale for a purchase price in excess of $10,000,000, such Asset Sale is for consideration at least 75% of which is cash or Permitted Investments (provided, however, that for the purposes of this clause (ii), each of the following shall be deemed to be cash: (A) any liabilities (as shown on the Borrower’s or such Subsidiary’s most recent balance sheet provided hereunder or in the footnotes thereto) of the Borrower or such Subsidiary, other than liabilities that are by their terms subordinated to the payment in cash of the Obligations, that are assumed by the transferee with respect to the applicable Asset Sale and for which the Borrower and all of the Subsidiaries shall have been validly released by all applicable creditors in writing and (B) any securities received by the Borrower or such Subsidiary from such transferee that are converted by the Borrower or such Subsidiary into cash (to the extent of the cash received) within 180 days following the closing of the applicable Asset Sale); (iii) such aggregate consideration is at least equal to the fair market value of the assets subject to such Asset Sale; (iv) the aggregate fair market value of all assets sold, transferred, leased or otherwise disposed of in reliance upon this paragraph (q) shall not exceed, (x) in any fiscal year of the Borrower, an amount equal to 10.0% of the PV-10 Value as of the end of the immediately preceding fiscal year, with unused amounts in any fiscal year being carried over to subsequent fiscal years and (y) during the term of this Agreement, 25.0% of the PV-10 Value of the Borrower and the Subsidiary Guarantors in the Initial Reserve Report in the aggregate; (v) the Net Cash Proceeds thereof are applied in accordance with Section 2.13; and (vi) the Proved Reserves Coverage Ratio, determined on a pro forma basis to exclude all PV-10 Value of the Borrower’s and the Subsidiary Guarantors’ Proved Reserves being disposed of in such Asset Sale and calculated as of the last day of the most recently ended fiscal year or the immediately preceding June 30, as applicable, shall be no less than 2.00 to 1.00.

To the extent any Collateral is Disposed of as expressly permitted by this Section 6.05 to any Person other than the Borrower or any Subsidiary Guarantor, such Collateral shall be sold free and clear of the Liens created by the Loan Documents without further action by the Administrative Agent, and the Administrative Agent shall be authorized to take any actions deemed appropriate in order to effect the foregoing.

F. Restricted Payments. Declare or make, or agree to declare or make, directly or indirectly, any Restricted Payment (including pursuant to any Synthetic Purchase Agreement), or incur any obligation (contingent or otherwise) to do so; provided, however, that

i. any Subsidiary may declare and pay dividends or make other distributions ratably to its equity holders;

ii. the Borrower and each Subsidiary may declare and make dividend payments or other distributions to the extent payable in the Equity Interests (other than Disqualified Stock not otherwise permitted by Section 6.01 or such dividend payments or distributions that would cause a Change in Control) of such Person;

iii. so long as no Event of Default or Default shall have occurred and be continuing or would result therefrom, the Borrower may declare or make, or agree to declare or make any Restricted Payment; provided that, (i) at the time of such Restricted Payment and after giving pro

 

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forma effect thereto as if such Restricted Payment had been made at the beginning of the applicable four-quarter period, the Leverage Ratio would be no greater than 4.00 to 1.00 and (ii) such Restricted Payment, together with the aggregate amount of all other Restricted Payments made by the Borrower pursuant to this Section 6.06(c) does not exceed the sum of (x) $10,000,000 in any fiscal year and $20,000,000 in the aggregate during the term of this Agreement, plus (y) up to 100% of the aggregate amount of the Net Cash Proceeds of Equity Issuances by or other cash contributions to the capital of the Borrower after the Closing Date (other than Disqualified Stock and Equity Issuances made pursuant to Section 7.02) and Not Otherwise Applied;

iv. so long as no Event of Default or Default shall have occurred and be continuing or would result therefrom, the Borrower may make Restricted Payments to Holdings the proceeds of which are used to repurchase the Equity Interests of Holdings or any Parent Entity owned by employees of Holdings, any Parent Entity, the Borrower or the Subsidiaries or make payments to employees of Holdings, any Parent Entity the Borrower or the Subsidiaries in connection with the exercise of stock options, stock appreciation rights or similar equity incentives or equity based incentives pursuant to management incentive plans or in connection with the death or disability of such employees in an aggregate amount not to exceed $7,500,000 in any fiscal year;

v. the Borrower may make Restricted Payments to Holdings in respect of (i) overhead, legal, accounting and other professional fees and expenses of Holdings or any Parent Entity not to exceed $7,500,000 in any fiscal year, (ii) reasonable and necessary fees and expenses related to any public offering or private placement of equity securities or debt (including any debt securities or bank loans) of, or any other transaction permitted to be undertaken pursuant to Section 6.21 by, Holdings or any Parent Entity whether or not consummated, (iii) fees and expenses (other than Taxes) incurred in connection with the maintenance of its (or its Parent Entity’s) existence and its (or any Parent Entity’s indirect) ownership of the Borrower, (iv) amounts necessary to enable Holdings to satisfy interest payment obligations in respect of the Holdings Notes when due, not to exceed amounts contemplated by the Holdings Notes Documents (as in effect on the Closing Date), (v) payments permitted by Section 6.08, and (vi) customary salary, bonus and other benefits payable to, and indemnities provided on behalf of, directors, officers and employees of Holdings or any Parent Entity, in each case in order to permit Holdings or any Parent Entity to make such payments; provided, that (a) in the case of clauses (i), (ii) and (iii), the amount of such Restricted Payments shall not exceed the portion of any amounts referred to in such clauses (i), (ii) and (iii) that are allocable to the Borrower and its Subsidiaries (which shall be 100% for so long as Holdings or such Parent Entity, as the case may be, owns no assets other than the Equity Interests in the Borrower, Holdings, or another Parent Entity) and (b) all Restricted Payments made to Holdings pursuant to this Section 6.06(e) are used by Holdings for the purposes specified herein within thirty (30) days after Holdings’ receipt thereof; and

vi. with respect to any taxable period for which Holdings or any Parent Entity files, as common parent, a consolidated, combined, affiliated or unitary income Tax return that includes Borrower (a “Consolidated Return”), Borrower may make Restricted Payments to Holdings or such Parent Entity (as applicable) in such amounts as shall be required by such common parent to pay the Tax liability due with respect to such Consolidated Return to the

 

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extent such Tax liability is directly attributable to the income of Borrower and the Subsidiaries included in such Consolidated Return (the “Borrower Consolidated Group”), but only to the extent the Borrower and the Subsidiaries have not otherwise made Restricted Payments or any other distributions or payments to satisfy such Tax liability (“Borrower Group Payments”); provided that the amount of Restricted Payments permitted under this clause with respect to any taxable period shall not exceed (x) the amount that the Borrower Consolidated Group would be required to pay in respect of U.S. federal, state and/or local income Taxes for such taxable period, determined taking into account any available net operating loss carryovers or other tax attributes of the Borrower Consolidated Group, as if the Borrower Consolidated Group filed a separate consolidated, combined, affiliated or unitary income Tax return, reduced by (y) any applicable Borrower Group Payments.

G. Restrictive Agreements. Enter into, incur or permit to exist any agreement or other arrangement that prohibits, restricts or imposes any condition upon (i) the ability of the Borrower or any Subsidiary to create, incur or permit to exist any Lien upon any of its property or assets, or (ii) the ability of any Subsidiary to pay dividends or other distributions with respect to any of its Equity Interests or to make or repay loans or advances to the Borrower or any other Subsidiary or to Guarantee Indebtedness of the Borrower or any other Subsidiary except:

i. restrictions and conditions imposed by law or by any Loan Document or any other debt permitted hereunder;

ii. customary restrictions and conditions contained in agreements relating to a Disposition pending such Disposition, provided such restrictions and conditions apply only to the assets that are to be sold and such sale is permitted hereunder;

iii. restrictions or conditions imposed by any agreement relating to secured Indebtedness permitted by this Agreement if such restrictions or conditions apply only to the property or assets securing such Indebtedness;

iv. customary provisions in leases and other contracts restricting the assignment thereof;

v. restrictions or conditions imposed by any agreement existing on the date hereof and listed on Schedule 6.07;

vi. restrictions or conditions which are binding on a Subsidiary at the time such Subsidiary first becomes a Subsidiary, so long as such restrictions or conditions were not created solely in contemplation of such Person becoming a Subsidiary, or are imposed by any permitted amendment, renewal, extension or refinancing of any such restriction or condition so long as the terms of any such amendment, renewal, extension or refinancing, taken as a whole, are not materially more restrictive (in the reasonable good faith determination of the Borrower) than such restriction or condition;

vii. restrictions or conditions which are customary provisions in joint venture agreements and other similar agreements applicable to joint ventures permitted under Section 6.04 and applicable solely to such joint venture entered; and

 

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viii. customary provisions restricting assignment of any agreement entered into in the ordinary course of business.

H. Transactions with Affiliates. Sell or transfer any property or assets to, or purchase or acquire any property or assets from, or otherwise engage in any other transactions (or series of related transactions) with, any of its Affiliates unless such transaction (or series of related transactions) is at prices and on terms and conditions no less favorable to the Borrower or such Subsidiary, as applicable, than would be obtained on an arm’s-length basis from unrelated third parties; provided that this Section 6.08 will not prohibit:

i. the Transactions;

ii. any indemnification agreement or any similar arrangement entered into with directors, officers, consultants and employees of the Borrower or any Subsidiary in the ordinary course of business and the payment of fees and indemnities to directors, officers, consultants and employees of the Borrower or any Subsidiary in the ordinary course of business; and customary obligations under any employment agreement entered into the ordinary course of business, and the payment of customary compensation to, and the reimbursement of expenses of, employees, officers or directors in the ordinary course of business;

iii. benefit programs or arrangements for employees, officers or directors, including, without limitation, vacation plans, health and life insurance plans, deferred compensation plans and retirement or savings plans, in each case in the ordinary course of business; any issuance of securities, or other payments, awards or grants in cash, securities or otherwise pursuant to, or the funding of, employment arrangements, stock options, stock ownership plans and the granting and performance of registration rights approved by the board of directors of the Borrower;

iv. Investments, Restricted Payments and other transactions expressly permitted by Article VI;

v. transactions specified on Schedule 6.08;

vi. transactions among the Loan Parties; and

vii. the payment of fees, reasonable out-of-pocket costs and indemnities to directors, officers, consultants and employees of Holdings, any Parent Entity, the Borrower and the Subsidiaries in the ordinary course of business (limited, in the case of any Parent Entity, to the portion of such fees and expenses that are allocable to the Borrower and its Subsidiaries (which shall be 100% for so long as Holdings or such Parent Entity, as the case may be, owns no assets other than the Equity Interests in the Borrower, Holdings or another Parent Entity and assets incidental to the ownership of the Borrower and its Subsidiaries)).

I. Business of Borrower and Subsidiaries; International Operations. (a) Engage to any material extent in any business or business activities other than the businesses engaged in by the Loan Parties on the Closing Date (after giving effect to the consummation of the Acquisition) and business activities reasonably incidental thereto within the geographical boundaries of the United States and subject to the jurisdiction of the United States or any business reasonably related, ancillary or complimentary thereto (including, without limitation, the exploration, development and production of Hydrocarbons); or (b) acquire or organize, directly or indirectly, any Foreign Subsidiaries.

 

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J. Certain Amendments and Modifications; Other Indebtedness.

i. Permit any waiver, supplement, modification, amendment, termination or release of any indenture, instrument or agreement pursuant to which any Material Indebtedness of the Borrower or any of the Subsidiaries is outstanding other than waivers, supplements, modifications, amendments, terminations or releases that do not materially increase the obligations of the obligor or confer additional material rights on the holder of such Indebtedness in a manner adverse in any material respect to any Agent or the Lenders and provided that the Borrower promptly furnishes to the Administrative Agent a copy of such waiver, supplement, modification, amendment, termination or release.

ii. Waive, supplement, modify or amend any Material Contract, to the extent any such waiver, supplement, modification or amendment would be adverse to the Lenders in any material respect, and provided that the Borrower promptly furnishes to the Administrative Agent a copy of such waiver, supplement, modification or amendment.

iii. Waive, supplement, modify or amend of its certificate of incorporation, by-laws, operating, management or partnership agreement or other organizational documents, to the extent any such waiver, supplement, modification or amendment would be adverse to the Lenders in any material respect, and provided that the Borrower promptly furnishes to the Administrative Agent a copy of such waiver, supplement, modification or amendment.

iv. Make any distribution, whether in cash, property, securities or a combination thereof, other than regular scheduled payments of principal and interest (or settlement payments in respect of Hedging Agreements) as and when due (to the extent not prohibited by applicable subordination provisions), in respect of, or pay, or commit to pay, or directly or indirectly (including pursuant to any Synthetic Purchase Agreement) redeem, repurchase, retire or otherwise acquire for consideration, or set apart any sum for the aforesaid purposes, any Indebtedness that is or is required to be subordinated to the Obligations pursuant to the terms of the Loan Documents except (i) the conversion of any such Indebtedness to Equity Interests (other than Disqualified Stock) of Holdings, (ii) refinancings of Indebtedness permitted by Section 6.01 and (iii) the payment of secured Indebtedness that becomes due as a result of the voluntary sale or transfer of the property or assets securing such Indebtedness.

K. [Reserved].

L. Maximum Leverage Ratio. Permit the Leverage Ratio as of the last day of any period of four consecutive fiscal quarters ending on any date set forth below, commencing with the period ending December 31, 2014 to be greater than the ratio set forth opposite such period below:

 

Date

  

Ratio

December 31, 2014    4.50 to 1.00
March 31, 2015    4.50 to 1.00
June 30, 2015    4.50 to 1.00
September 30, 2015    4.50 to 1.00

December 31, 2015 and the last day

of each fiscal quarter thereafter

   3.00 to 1.00

 

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M. [Reserved].

N. Fiscal Year. With respect to the Borrower and its Consolidated Subsidiaries, change their fiscal year-end to a date other than December 31.

O. Hedging Agreements. Enter into any commodity Hedging Agreement (a) with any Person other than an Approved Counterparty, (b) for notional volumes which, when aggregated with other commodity Hedging Agreements then in effect other than puts, floors and basis differential swaps on volumes already hedged pursuant to other Hedging Agreements, exceed, as of the date such Hedging Agreement is executed, 80% of the sum of (x) Forecasted Proved Reserve Production and (y) reasonably forecasted production from Proved Reserves not reflected in the most recent Reserve Report delivered pursuant to this Agreement, for the first 24-month period following such date, it being understood that such Hedging Agreement may have a term beyond 24 months or (c) for speculative purposes or for reasons other than as a part of its normal business operations as a risk management strategy and/or hedge against changes resulting from market conditions related to the operations of the Loan Parties.

P. Certain Equity Securities. Issue any Equity Interest that is not Qualified Capital Stock.

Q. Limitation on Leases. Create, incur, assume or suffer to exist any obligation for the payment of rent or hire of property of any kind whatsoever (real or personal but excluding Capital Lease Obligations, leases of drilling rigs in the ordinary course of business and leases of Hydrocarbon Interests), under leases or lease agreements which would cause the aggregate amount of all payments made by the Borrower and the Subsidiaries pursuant to all such leases or lease agreements, including, without limitation, any residual payments at the end of any lease, to exceed $10,000,000 in any period of twelve consecutive calendar months during the life of such leases.

R. Sale or Discount of Receivables. Discount or sell (with or without recourse) any of its notes receivable or accounts receivable except for receivables obtained by the Borrower or any Subsidiary outside of the ordinary course of business or the settlement of joint interest billing accounts in the ordinary course of business or discounts granted to settle collection of accounts receivable or the sale of defaulted accounts arising in the ordinary course of business in connection with the compromise or collection thereof and not in connection with any financing transaction.

S. Gas Balancing Agreements and Advance Payment Contracts. Other than as set forth on Schedule 3.26, allow gas imbalances, take-or-pay or other prepayments with respect to the Oil and Gas Properties of the Borrower or any Subsidiary that would require the Borrower or such Subsidiary to deliver Hydrocarbons at some future time without then or thereafter receiving

 

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full payment therefor exceeding five percent (5.0%) or more of the average monthly production of Hydrocarbons (with such average calculated with respect to the twelve (12) months most recently completed prior to any date of determination) produced from such Oil and Gas Properties in the aggregate.

T. Marketing Activities. Engage in marketing activities for any Hydrocarbons or enter into any contracts related thereto other than (i) contracts for the sale of Hydrocarbons scheduled or reasonably estimated to be produced from their proved Oil and Gas Properties during the period of such contract, (ii) contracts for the sale of Hydrocarbons scheduled or reasonably estimated to be produced from proved Oil and Gas Properties of third parties during the period of such contract associated with the Oil and Gas Properties of the Borrower and its Subsidiaries that the Borrower or one of its Subsidiaries has the right to market pursuant to joint operating agreements, unitization agreements or other similar contracts that are usual and customary in the oil and gas business, and (iii) other contracts for the purchase and/or sale of Hydrocarbons of third parties either (A) (x) which have generally offsetting provisions (i.e., corresponding pricing mechanics, delivery dates and points and volumes) such that no “position” is taken and (y) for which appropriate credit support has been taken to alleviate the material credit risks of the counterparty thereto or (B) are cancelable on 120 days’ notice or less without penalty or detriment.

U. Holdings Covenants. Holdings covenants and agrees with each Lender that, until the Commitments have been terminated and the principal of and interest on each Loan, all Fees and all other expenses or amounts payable under any Loan Document have been paid in full, unless the Required Lenders shall otherwise consent in writing,

(a) Holdings will not (i) conduct, transact or otherwise engage in any active trade or business or operations other than through the Borrower and its Subsidiaries (and, for the avoidance of doubt, through Persons or assets that are the subject of clause (III) of the proviso below) or (ii) own or hold any assets (other than the Equity Interests of the Borrower and H2 Midstream LLC, cash and Permitted Investments and any immaterial assets) or incur any liabilities (other than its Guarantee in respect of the Obligations and its obligations pursuant to the Security Documents, liabilities under the Chesapeake Note, liabilities under the Holdings Notes Documents and this Section 6.21, immaterial liabilities and liabilities incurred in connection with the maintenance of its (or its Parent Entity’s) existence and its (or any Parent Entity’s indirect) ownership of the Borrower (including the payment of taxes and similar administrative expenses associated with being a holding company, the participation in tax, accounting and other administrative matters as a member of the consolidated group including Holdings and the Borrower, and the indemnification of officers and directors)); provided that this clause (a) shall not prohibit Holdings from (I) making any public offering of its common stock or any other issuance of its Equity Interests not constituting a Change in Control, (II) engaging in financing activities, including the issuance of securities, incurrence of debt, payment of dividends, distributions, redemptions, repurchases, retirements or other acquisitions for value of its Equity Interests, contributions to the capital of the Borrower and its Subsidiaries and Guarantees of the obligations of the Borrower and its Subsidiaries, (III) making Investments and otherwise acquiring, constructing or improving assets (and any subsequent Disposition of any such Investments or assets) (provided that the aggregate amount expended by Holdings on such Investments, acquisitions, constructions and improvements shall not exceed (A) prior to a

 

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Qualified IPO, $75,000,000, and (B) during the term of this Agreement, $150,000,000), (IV) engaging in activities necessary or advisable to consummate the Transactions (including the payment of Transaction Costs) or (V) engaging in activities incidental or reasonably related to the activities permitted by this Section 6.21;

(b) Holdings will not create, incur, assume or permit to exist any Lien (other than Liens of a type described in clauses (a), (c) or (h) of the definition of “Excepted Lien”) on any of the Equity Interests issued by the Borrower;

(c) not later than the fifth Business Day following the receipt of the Net Cash Proceeds of a Qualified IPO, Holdings shall apply such Net Cash Proceeds to the repayment in full of the Chesapeake Note (if still outstanding on such date); and

(d) Holdings shall do or cause to be done all things necessary to preserve, renew and keep in full force and effect its legal existence; provided that so long as no Default exists or would result therefrom, Holdings may merge, amalgamate or consolidate with or into any other person or otherwise convey, sell, assign or transfer all or substantially all of its assets or property; provided that Holdings shall be the continuing or surviving person or, in the case of a merger, amalgamation, consolidation, conveyance, sale, assignment or transfer where Holdings is not the continuing or surviving person (i) the person formed by or surviving any such merger, amalgamation or consolidation or the person into which Holdings has been or to which Holdings has transferred such shall be organized under the laws of a state in the United States and shall expressly assume all the obligations of Holdings under this Agreement and the other Loan Documents pursuant to a supplement hereto or thereto in form reasonably satisfactory to the Administrative Agent (and the Administrative Agent, if it so requests, shall receive a legal opinion from outside counsel to the survivor reasonably satisfactory to the Administrative Agent) and (ii) thereafter, such person will succeed to, and be substituted for, Holdings under this Agreement for all purposes.

7.

Events of Default

A. Events of Default. In case of the happening of any of the following events (“Events of Default):

i. any representation or warranty made or deemed made in or in connection with any Loan Document or the borrowings hereunder, or any representation, warranty, statement or information contained in any report, certificate, financial statement or other instrument furnished in connection with or pursuant to any Loan Document, shall prove to have been false or misleading in any material respect when so made, deemed made or furnished;

ii. default shall be made in the payment of any principal of any Loan when and as the same shall become due and payable, whether at the due date thereof or at a date fixed for prepayment thereof or by acceleration thereof or otherwise;

iii. default shall be made in the payment of any interest on any Loan or any Fee or any other amount (other than an amount referred to in (b) above) due under any Loan Document, when and as the same shall become due and payable, and such default shall continue unremedied for a period of five Business Days;

 

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iv. default shall be made in the due observance or performance by Holdings, the Borrower or any Subsidiary of any covenant, condition or agreement contained in Section 5.01(a) (solely with respect to the existence of the Borrower), 5.03 (with respect to the requirement to maintain insurance set forth therein), 5.06(a) or 5.09 or in Article VI; provided that any Event of Default under Section 6.12 is subject to cure as contemplated by Section 7.02;

v. default shall be made in the due observance or performance by Holdings, the Borrower or any Subsidiary of any covenant, condition or agreement contained in any Loan Document (other than those specified in (b), (c) or (d) above) and such default shall continue unremedied for a period of 30 days after the earlier of (i) notice thereof from the Administrative Agent to the Borrower (which notice shall also be given at the request of any Lender) or (ii) knowledge thereof of a Responsible Officer of the Borrower; provided, however, that if the Borrower fails to deliver any financial statements, certificates or other information within the time period required by Sections 5.05, 5.06 (other than Section 5.06(a)), 5.13, 5.14, 5.15 or 5.16 and subsequently delivers such financial statements, certificates or other information as required by such Sections prior to acceleration or the exercise of any remedy by the Lenders, then such Event of Default shall be deemed to have been cured without any further action by the Administrative Agent or Lenders;

vi. Holdings, the Borrower or any Subsidiary shall (i) fail to pay any principal or interest, regardless of amount, due in respect of any Material Indebtedness, when and as the same shall become due and payable (including becoming due prior to its scheduled maturity, and after any applicable grace period with respect thereto), or (ii) default in the observance or performance of any other agreement or condition contained in any agreement governing any Material Indebtedness or any other event shall occur or condition exist, the effect of which default or other event or condition is to cause, or to permit the holder or holders of any Material Indebtedness or any trustee or agent on its or their behalf to cause, with the giving of notice, if required, such Material Indebtedness to become due, or to require the prepayment, repurchase, redemption or defeasance thereof, prior to its scheduled maturity; provided that this clause (ii) shall not apply to secured Indebtedness that becomes due solely as a result of the voluntary sale or transfer of the property or assets securing such Indebtedness that is permitted hereunder;

vii. an involuntary proceeding shall be commenced or an involuntary petition shall be filed in a court of competent jurisdiction seeking (i) relief in respect of Holdings, the Borrower or any Subsidiary, or of a substantial part of the property or assets of Holdings, the Borrower or a Subsidiary, under any Debtor Relief Law, (ii) the appointment of a receiver, receiver and manager, trustee, custodian, sequestrator, conservator or similar official for Holdings, the Borrower or any Subsidiary or for a substantial part of the property or assets of Holdings, the Borrower or a Subsidiary, or (iii) the winding-up or liquidation of Holdings, the Borrower or any Subsidiary; and such proceeding or petition shall continue undismissed for 60 days or an order or decree approving or ordering any of the foregoing shall be entered;

viii. Holdings, the Borrower or any Subsidiary shall (i) voluntarily commence any proceeding or file any petition seeking relief under any Debtor Relief Law, (ii) consent to the

 

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institution of, or fail to contest in a timely and appropriate manner, any proceeding or the filing of any petition described in (g) above, (iii) apply for or consent to the appointment of a receiver, trustee, custodian, sequestrator, conservator or similar official for Holdings, the Borrower or any Subsidiary or for a substantial part of the property or assets of Holdings, the Borrower or any Subsidiary, (iii) file an answer admitting the material allegations of a petition filed against it in any such proceeding, (iv) make a general assignment for the benefit of creditors, (v) become unable, admit in writing its inability or fail generally to pay its debts as they become due, or (vi) take any action for the purpose of effecting any of the foregoing;

ix. one or more final judgments for the payment of money shall be rendered against Holdings, the Borrower, any Subsidiary or any combination thereof and the same shall remain undischarged for a period of 60 consecutive days during which execution shall not be effectively stayed, or any action shall be legally taken by a judgment creditor to levy upon assets or properties of Holdings, the Borrower or any Subsidiary to enforce any such judgment and, in each case, such judgment is for the payment of money in an aggregate amount in excess of $25,000,000 (to the extent not covered by independent third party insurance as to which the insurer does not dispute coverage and is not subject to an insolvency proceeding);

x. an ERISA Event shall have occurred that, in the opinion of the Required Lenders, when taken together with all other such ERISA Events, could reasonably be expected to result in liability of the Borrower and its ERISA Affiliates in an aggregate amount exceeding $25,000,000; or

xi. any Guarantee under the Guarantee and Collateral Agreement for any reason shall cease to be in full force and effect (other than in accordance with its terms), or any Guarantor shall deny in writing that it has any further liability under the Guarantee and Collateral Agreement (other than as a result of the discharge of such Guarantor in accordance with the terms of the Loan Documents);

xii. the Loan Documents after delivery thereof shall for any reason, except to the extent permitted by the terms thereof, cease to be in full force and effect and valid, binding and enforceable in accordance with their terms against the Borrower or a Guarantor party thereto, or shall be repudiated by any of them, or cease to create valid and perfected Liens of the priority required thereby on the Collateral purported to be covered thereby, except to the extent permitted by the terms of this Agreement or the Security Documents and except to the extent that any such loss of perfection or priority results from the failure of either of the Administrative Agent or the Collateral Agent to maintain possession of certificates actually delivered to it representing securities pledged under the Security Documents or to file Uniform Commercial Code continuation statements and except as to Collateral consisting of real property to the extent that such losses are covered by a lender’s title insurance policy and such insurer has not disputed coverage, or the Borrower or any Guarantor or any of their Affiliates shall so state in writing; or

xiii. there shall have occurred a Change in Control;

then, and in every such event (other than an event with respect to the Borrower described in paragraph (g) or (h) above), and at any time thereafter during the continuance of such event, the Administrative Agent, shall the Required Lenders so direct, by notice to the Borrower, take

 

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either or both of the following actions, at the same or different times: (i) terminate forthwith the Commitments and (ii) declare the Loans then outstanding to be forthwith due and payable in whole or in part, whereupon the principal of the Loans so declared to be due and payable, together with the Applicable Premium, accrued interest thereon and any unpaid accrued Fees and all other liabilities of the Borrower accrued hereunder and under any other Loan Document, shall become forthwith due and payable, without presentment, demand, protest or any other notice of any kind, all of which are hereby expressly waived by the Borrower, anything contained herein or in any other Loan Document to the contrary notwithstanding; and in any event with respect to the Borrower described in paragraph (g) or (h) above, the Commitments shall automatically terminate and the principal of the Loans then outstanding, together with the Applicable Premium, accrued interest thereon and any unpaid accrued Fees and all other liabilities of the Borrower accrued hereunder and under any other Loan Document, shall automatically become due and payable, without presentment, demand, protest or any other notice of any kind, all of which are hereby expressly waived by the Borrower, anything contained herein or in any other Loan Document to the contrary notwithstanding.

B. Borrower’s Right to Cure. i. Notwithstanding anything to the contrary contained in Section 7.01, but subject to Section 7.02(c), in the event that the Borrower fails (or, but for the operation of this Section 7.02, would fail) to comply with the requirements of the covenant set forth in Section 6.12 (the “Financial Performance Covenant”) at the end of any fiscal quarter, until the expiration of the 20th day subsequent to the date the certificate calculating the Leverage Ratio is required to be delivered pursuant to Section 5.05(c) with respect to such fiscal quarter, the Borrower shall have the right to issue Permitted Cure Securities for cash or otherwise receive cash contributions to the capital of the Borrower (collectively, the “Cure_Right”), and upon the receipt by the Borrower of such cash (the “Cure Amount”) pursuant to the exercise by the Borrower of such Cure Right, the Financial Performance Covenant shall be recalculated on a pro forma basis such that Consolidated EBITDAX is increased for such fiscal quarter (and future four fiscal quarter periods which include such fiscal quarter), solely for the purpose of measuring the Financial Performance Covenant and not for any other purpose under this Agreement, by an amount equal to the Cure Amount.

ii. If, after giving effect to the foregoing recalculations, the Borrower shall then be in compliance with the requirements of the Financial Performance Covenant, then the Borrower shall be deemed to have satisfied the requirements of the Financial Performance Covenant as of the relevant date of determination with the same effect as though there had been no failure to comply therewith at such date, and the applicable breach or default of the Financial Performance Covenant that had occurred shall be deemed cured for the purposes of the Loan Documents.

iii. Notwithstanding anything herein to the contrary, (i) in each period of four fiscal quarters there shall be at least two fiscal quarters in which the Cure Right is not exercised, (ii) the Cure Right may not be exercised more than five times in the aggregate during the term of this Agreement and (iii) for purposes of this Section 7.02, the Cure Amount shall be no greater than the amount required for purposes of complying with the Financial Performance Covenant.

 

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8.

The Administrative Agent and the Collateral Agent; Etc.

A. Appointment and Authority. Each Lender hereby irrevocably appoints the Administrative Agent and the Collateral Agent (for purposes of this Article VIII, the Administrative Agent and the Collateral Agent are referred to collectively as the “Agents”) its agent and authorizes the Agents to take such actions on its behalf and to exercise such powers as are delegated to such Agent by the terms of the Loan Documents, together with such actions and powers as are reasonably incidental thereto. Without limiting the generality of the foregoing, the Agents are hereby expressly authorized to (i) execute any and all documents (including releases) with respect to the Collateral and the rights of the Lenders with respect thereto, as contemplated by and in accordance with the provisions of this Agreement and the Security Documents and (ii) negotiate, enforce or the settle any claim, action or proceeding affecting the Lenders in their capacity as such, at the direction of the Required Lenders, which negotiation, enforcement or settlement will be binding upon each Lender.

B. Rights as a Lender. The institution serving as the Administrative Agent and/or the Collateral Agent hereunder shall have the same rights and powers in its capacity as a Lender as any other Lender and may exercise the same as though it were not an Agent, and such institution and its Affiliates may accept deposits from, lend money to and generally engage in any kind of business with the Borrower or any Subsidiary or other Affiliate thereof as if it were not an Agent hereunder.

C. Exculpatory Provisions. i. No Agent shall have any duties or obligations except those expressly set forth in the Loan Documents. Without limiting the generality of the foregoing, (i) no Agent shall be subject to any fiduciary or other implied duties, regardless of whether a Default has occurred and is continuing, (ii) no Agent shall have any duty to take any discretionary action or exercise any discretionary powers, except discretionary rights and powers expressly contemplated hereby that such Agent is instructed in writing to exercise by the Required Lenders (or such other number or percentage of the Lenders as shall be necessary under the circumstances as provided in Section 9.08), and (iii) except as expressly set forth in the Loan Documents, no Agent shall have any duty to disclose, nor shall it be liable for the failure to disclose, any information relating to the Borrower or any of the Subsidiaries that is communicated to or obtained by the institution serving as Administrative Agent and/or Collateral Agent or any of its Affiliates in any capacity.

(a) No Agent shall be liable for any action taken or not taken by it with the consent or at the request of the Required Lenders (or such other number or percentage of the Lenders as shall be necessary under the circumstances as provided in Section 9.08) or in the absence of its own gross negligence or willful misconduct. No Agent shall be deemed to have knowledge of any Default unless and until written notice thereof is given to such Agent by the Borrower or a Lender.

(b) No Agent shall be responsible for or have any duty to ascertain or inquire into (i) any statement, warranty or representation made in or in connection with any Loan Document, (ii) the contents of any certificate, report or other document delivered thereunder or in connection therewith, (iii) the performance or observance of any of the

 

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covenants, agreements or other terms or conditions set forth in any Loan Document, (iv) the validity, enforceability, effectiveness or genuineness of any Loan Document or any other agreement, instrument or document, or (v) the satisfaction of any condition set forth in Article IV or elsewhere in any Loan Document, other than to confirm receipt of items expressly required to be delivered to such Agent.

D. Reliance by Agent. Each Agent shall be entitled to rely upon, and shall not incur any liability for relying upon, any notice, request, certificate, consent, statement, instrument, document or other writing (including any electronic message, Internet or intranet website posting or other distribution) believed by it to be genuine and to have been signed or sent by the proper Person. Each Agent may also rely upon any statement made to it orally or by telephone and believed by it to have been made by the proper Person, and shall not incur any liability for relying thereon. Each Agent may consult with legal counsel (who may be counsel for the Borrower), independent accountants and other experts selected by it, and shall not be liable for any action taken or not taken by it in accordance with the advice of any such counsel, accountants or experts.

E. Delegation of Duties. Each Agent may perform any and all its duties and exercise its rights and powers by or through any one or more sub-agents (other than a Disqualified Lender) appointed by it. Each Agent and any such sub-agent may perform any and all its duties and exercise its rights and powers by or through their respective Related Parties. The exculpatory provisions of the preceding paragraphs shall apply to any such sub-agent and to the Related Parties of each Agent and any such sub-agent, and shall apply to their respective activities in connection with the syndication of the Credit Facility as well as activities as Agent. No Agent shall be responsible for the negligence or misconduct of any sub-agents except to the extent that a court of competent jurisdiction determines in a final and non-appealable judgment that the applicable Agent acted with gross negligence or willful misconduct in the selection of such sub agents.

F. Resignation of Agent. Subject to the appointment and acceptance of a successor Agent as provided below, any Agent may resign at any time by notifying the Lenders and the Borrower. Upon any such resignation, the Required Lenders shall have the right, with the consent of the Borrower so long as no Event of Default has occurred and is continuing, to appoint a successor (which shall not be a Disqualified Lender). If no successor shall have been so appointed by the Required Lenders (with the consent of the Borrower, if applicable) and shall have accepted such appointment within 30 days after the retiring Agent gives notice of its resignation, then the retiring Agent may, on behalf of the Lenders, appoint a successor Agent which shall be a bank with an office in New York, New York, or an Affiliate of any such bank, but shall not be a Disqualified Lender. If no successor Agent has been appointed pursuant to the immediately preceding sentence by the 30th day after the date such notice of resignation was given by such Agent, such Agent’s resignation shall become effective and the Required Lenders shall thereafter perform all the duties of such Agent hereunder and/or under any other Loan Document until such time, if any, as the Required Lenders, with the consent of the Borrower so long as no Event of Default has occurred and is continuing, appoint a successor Administrative Agent and/or Collateral Agent, as the case may be. Upon the acceptance of its appointment as Agent hereunder by a successor, such successor shall succeed to and become vested with all the rights, powers, privileges and duties of the retiring Agent, and the retiring Agent shall be

 

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discharged from its duties and obligations hereunder. The fees payable by the Borrower to a successor Agent shall be the same as those payable to its predecessor unless otherwise agreed between the Borrower and such successor. After an Agent’s resignation hereunder, the provisions of this Article and Section 9.05 shall continue in effect for the benefit of such retiring Agent, its sub-agents and their respective Related Parties in respect of any actions taken or omitted to be taken by any of them while acting as Agent.

G. Non-Reliance on Agent and Other Lenders. Each Lender acknowledges that it has, independently and without reliance upon the Agents or any other Lender and based on such documents and information as it has deemed appropriate, made its own credit analysis and decision to enter into this Agreement. Each Lender also acknowledges that it will, independently and without reliance upon the Agents or any other Lender and based on such documents and information as it shall from time to time deem appropriate, continue to make its own decisions in taking or not taking action under or based upon this Agreement or any other Loan Document, any related agreement or any document furnished hereunder or thereunder.

H. No Other Duties. Notwithstanding any other provision of this Agreement or any provision of any other Loan Document, each of the Arrangers is named as such for recognition purposes only, and in their respective capacities as such shall have no duties, responsibilities or liabilities with respect to this Agreement or any other Loan Document; it being understood and agreed that each of the Arrangers shall be entitled to all indemnification and reimbursement rights in favor of the Agents provided herein and in the other Loan Documents. Without limitation of the foregoing, neither of the Arrangers in their capacities as such shall, by reason of this Agreement or any other Loan Document, have any fiduciary relationship in respect of any Lender, Loan Party or any other Person.

I. Collateral and Guaranty Matters. (a) The Secured Parties irrevocably authorize the Collateral Agent,

(i) to release any Lien on any property granted to or held by the Administrative Agent under any Loan Document (x) upon termination of all Commitments, termination of all Hedging Agreements with Approved Counterparties that are secured by the Liens on the Collateral (other than Hedging Agreements with any Approved Counterparty with respect to which other arrangements satisfactory to the Approved Counterparty and the applicable Loan Party have been made), and payment in full of all Obligations (other than (A) obligations under Hedging Agreements and obligations under Cash Management Agreements not yet due and payable and (B) indemnification obligations not yet due and payable of which the Borrower has not received a notice of potential claim), (y) that is sold or otherwise disposed of or to be sold or otherwise disposed of as part of or in connection with any sale or other disposition permitted under the Loan Documents, or (z) if approved, authorized or ratified in writing by the Required Lenders; and

(ii) to release any Guarantor from its obligations under the Guarantee and Collateral Agreement if such Person ceases to be a Subsidiary as a result of a transaction permitted under the Loan Documents.

 

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(b) Upon request by the Collateral Agent at any time, the Secured Parties will confirm in writing the Collateral Agent’s authority to release its interest in particular types or items of property, or to release any Guarantor from its obligations under the Guarantee and Collateral Agreement pursuant to this Section 8.09. By accepting the benefit of the Liens granted pursuant to the Security Documents, each Secured Party not party hereto hereby agrees to the terms of this Section 8.09.

9.

Miscellaneous

A. Notices; Electronic Communications. Notices and other communications provided for herein shall be in writing and shall be delivered by hand or overnight courier service, mailed by certified or registered mail or sent by fax, as follows:

i. if to the Borrower, to it at Energy & Exploration Partners, LLC, Two City Place, Suite 1700, 100 Throckmorton, Fort Worth, TX 76102, Attention of Brian Nelson, Email: bnelson@enxp.com;

ii. if to Holdings or any Subsidiary, to it in care of the Borrower at the address set forth above;

iii. if to the Administrative Agent, to Credit Suisse, Agency Manager, Eleven Madison Avenue, New York, NY 10010, Fax No. 212-322-2291, Email: agency.loanops@credit-suisse.com;

iv. if to the Collateral Agent, to it at Credit Suisse, Eleven Madison Avenue, 23rd Floor, New York, NY 10010, Attention: Loan Operations – Boutique Management, Telephone No.: (212) 538-3525, Email: Ops-collateral@credit-suisse.com; and

v. if to a Lender, to it at its address (or fax number) set forth in the Assignment and Acceptance pursuant to which such Lender shall have become a party hereto.

All notices and other communications given to any party hereto in accordance with the provisions of this Agreement shall be deemed to have been given on the date of receipt if delivered by hand or overnight courier service or sent by fax or on the date five Business Days after dispatch by certified or registered mail if mailed, in each case delivered, sent or mailed (properly addressed) to such party as provided in this Section 9.01 or in accordance with the latest unrevoked direction from such party given in accordance with this Section 9.01. As agreed to among the Borrower, the Administrative Agent and the applicable Lenders from time to time, notices and other communications may also be delivered by e-mail to the e-mail address of a representative of the applicable Person provided from time to time by such Person.

The Borrower hereby agrees, unless directed otherwise by the Administrative Agent or unless the electronic mail address referred to below has not been provided by the Administrative Agent to the Borrower, that it will, or will cause its Subsidiaries to, provide to the Administrative Agent all information, documents and other materials that it is obligated to furnish to the Administrative Agent pursuant to the Loan Documents or to the Lenders under Article 5, including all notices, requests, financial statements, financial and other reports, certificates and

 

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other information materials, but excluding any such communication that (i) is or relates to a Borrowing Request or a notice pursuant to Section 2.10, (ii) relates to the payment of any principal or other amount due under this Agreement prior to the scheduled date therefor, (iii) provides notice of any Default or Event of Default under this Agreement or any other Loan Document or (iv) is required to be delivered to satisfy any condition precedent to the effectiveness of this Agreement and/or any Borrowing or other extension of credit hereunder (all such non-excluded communications being referred to herein collectively as “Communications”), by transmitting the Communications in an electronic/soft medium that is properly identified in a format acceptable to the Administrative Agent to an electronic mail address as directed by the Administrative Agent. In addition, the Borrower agrees, and agrees to cause its Subsidiaries, to continue to provide the Communications to the Administrative Agent or the Lenders, as the case may be, in the manner specified in the Loan Documents but only to the extent requested by the Administrative Agent.

The Borrower hereby acknowledges that (a) the Administrative Agent will make available to the Lenders materials and/or information provided by or on behalf of the Borrower hereunder (collectively, the “Borrower Materials”) by posting the Borrower Materials on Intralinks or another similar electronic system (the “Platform”) and (b) certain of the Lenders may be “public-side” Lenders (i.e., Lenders that do not wish to receive material non-public information with respect to the Borrower or its securities) (each, a “Public Lender”). The Borrower hereby agrees that (w) all Borrower Materials that are to be made available to Public Lenders shall be clearly and conspicuously marked “PUBLIC” which, at a minimum, shall mean that the word “PUBLIC” shall appear prominently on the first page thereof; (x) by marking Borrower Materials “PUBLIC,” the Borrower shall be deemed to have authorized the Administrative Agent and the Lenders to treat such Borrower Materials as not containing any material non-public information with respect to the Borrower or its securities for purposes of United States Federal and state securities laws (provided, however, that to the extent such Borrower Materials constitute Information, they shall be treated as set forth in Section 9.16); (y) all Borrower Materials marked “PUBLIC” are permitted to be made available through a portion of the Platform designated as “Public Investor;” and (z) the Administrative Agent shall be entitled to treat any Borrower Materials that are not marked “PUBLIC” as being suitable only for posting on a portion of the Platform not marked as “Public Investor.” Notwithstanding the foregoing, the following Borrower Materials shall be deemed to be marked “PUBLIC”, unless the Borrower notifies the Administrative Agent promptly that any such document contains material non-public information: (1) the Loan Documents, (2) notification of changes in the terms of the Credit Facility and (3) all information delivered pursuant to Sections 5.05(a), (b) and (c).

Each Public Lender agrees to cause at least one individual at or on behalf of such Public Lender to at all times have selected the “Private Side Information” or similar designation on the content declaration screen of the Platform in order to enable such Public Lender or its delegate, in accordance with such Public Lender’s compliance procedures and applicable law, including United States Federal and state securities laws, to make reference to Communications that are not made available through the “Public Side Information” portion of the Platform and that may contain material non-public information with respect to the Borrower or its securities for purposes of United States Federal or state securities laws.

 

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THE PLATFORM IS PROVIDED “AS IS” AND “AS AVAILABLE”. NEITHER THE ADMINISTRATIVE AGENT NOR ANY OF ITS RELATED PARTIES WARRANTS THE ACCURACY OR COMPLETENESS OF THE COMMUNICATIONS OR THE ADEQUACY OF THE PLATFORM AND EACH EXPRESSLY DISCLAIMS LIABILITY FOR ERRORS OR OMISSIONS IN THE COMMUNICATIONS. NO WARRANTY OF ANY KIND, EXPRESS, IMPLIED OR STATUTORY, INCLUDING ANY WARRANTY OF MERCHANTABILITY, FITNESS FOR A PARTICULAR PURPOSE, NON-INFRINGEMENT OF THIRD PARTY RIGHTS OR FREEDOM FROM VIRUSES OR OTHER CODE DEFECTS IS MADE BY THE ADMINISTRATIVE AGENT OR ANY OF ITS RELATED PARTIES IN CONNECTION WITH THE COMMUNICATIONS OR THE PLATFORM. IN NO EVENT SHALL THE ADMINISTRATIVE AGENT OR ANY OF ITS RELATED PARTIES HAVE ANY LIABILITY TO ANY LOAN PARTY, ANY LENDER OR ANY OTHER PERSON FOR DAMAGES OF ANY KIND, WHETHER OR NOT BASED ON STRICT LIABILITY AND INCLUDING DIRECT OR INDIRECT, SPECIAL, INCIDENTAL OR CONSEQUENTIAL DAMAGES, LOSSES OR EXPENSES (WHETHER IN TORT, CONTRACT OR OTHERWISE) ARISING OUT OF ANY LOAN PARTY’S OR THE ADMINISTRATIVE AGENT’S TRANSMISSION OF COMMUNICATIONS THROUGH THE INTERNET, EXCEPT TO THE EXTENT THE LIABILITY OF ANY SUCH PERSON IS FOUND IN A FINAL RULING BY A COURT OF COMPETENT JURISDICTION TO HAVE RESULTED PRIMARILY FROM SUCH PERSON’S GROSS NEGLIGENCE OR WILLFUL MISCONDUCT.

The Administrative Agent agrees that the receipt of the Communications by the Administrative Agent at its e-mail address set forth above shall constitute effective delivery of the Communications to the Administrative Agent for purposes of the Loan Documents. Each Lender agrees that receipt of notice to it (as provided in the next sentence) specifying that the Communications have been posted to the Platform shall constitute effective delivery of the Communications to such Lender for purposes of the Loan Documents. Each Lender agrees to notify the Administrative Agent in writing (including by electronic communication) from time to time of such Lender’s e-mail address to which the foregoing notice may be sent by electronic transmission and that the foregoing notice may be sent to such e-mail address.

Nothing herein shall prejudice the right of the Administrative Agent or any Lender to give any notice or other communication pursuant to any Loan Document in any other manner specified in such Loan Document.

B. Survival of Agreement. All covenants, agreements, representations and warranties made by the Borrower herein and in the certificates or other instruments prepared or delivered in connection with or pursuant to this Agreement or any other Loan Document shall be considered to have been relied upon by the Lenders and shall survive the making by the Lenders of the Loans, regardless of any investigation made by the Lenders or on their behalf, and shall continue in full force and effect as long as the principal of or any accrued interest on any Loan or any Fee or any other amount payable under this Agreement or any other Loan Document is outstanding and unpaid and so long as the Commitments have not been terminated. The provisions of Sections 2.14, 2.16, 2.20 and 9.05 shall remain operative and in full force and effect regardless of the expiration of the term of this Agreement, the consummation of the transactions contemplated hereby, the repayment of any of the Loans, the expiration of the

 

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Commitments, the invalidity or unenforceability of any term or provision of this Agreement or any other Loan Document, or any investigation made by or on behalf of the Administrative Agent, the Collateral Agent or any Lender.

C. Binding Effect. This Agreement shall become effective when it shall have been executed by the Borrower and the Administrative Agent and when the Administrative Agent shall have received counterparts hereof which, when taken together, bear the signatures of each of the other parties hereto.

D. Successors and Assigns. i. Whenever in this Agreement any of the parties hereto is referred to, such reference shall be deemed to include the permitted successors and assigns of such party; and all covenants, promises and agreements by or on behalf of the Borrower, the Administrative Agent, the Collateral Agent, the Lenders or the other Secured Parties that are contained in this Agreement shall bind and inure to the benefit of their respective successors and assigns. Notwithstanding the foregoing, when (i) any Secured Party assigns or otherwise transfers any interest held by it under any Hedging Agreement to any other Person pursuant to the terms of such agreement, or (ii) any Secured Party transfers any Cash Management Agreement to any other Person, in each case, that other Person shall thereupon become vested with all the benefits held by such Secured Party under this Agreement and the other Loan Documents only if such Person is also then a Lender, an Arranger, an Agent, an Affiliate of a Lender, an Affiliate of an Arranger, or an Affiliate of a Lender or, in the case of clause (i) only, a Secured Non-Lender Hedge Provider.

ii. Each Lender may assign to one or more Eligible Assignees all or a portion of its interests, rights and obligations under this Agreement (including all or a portion of its Commitment and the Loans at the time owing to it), with the prior written consent of (x) the Administrative Agent (other than with respect to assignments (I) pursuant to Section 9.04(k) or 9.04(l) or (II) to a Lender, an Affiliate of a Lender or a Related Fund, and not to be unreasonably withheld or delayed) and (y) the Borrower (other than during the continuance of an Event of Default pursuant to Section 7.01(b), (c), (g) or (h), and other than with respect to assignments to a Lender, an Affiliate of a Lender or a Related Fund, and not to be unreasonably withheld or delayed) (provided that the Borrower shall be deemed to have consented to any assignment unless the Borrower has objected thereto by written notice to the Administrative Agent within ten Business Days after having received notice thereof); provided, however, that (i) the amount of the Commitment or Loans of the assigning Lender subject to each such assignment (determined as of the date the Assignment and Acceptance with respect to such assignment is delivered to the Administrative Agent) shall be in an integral multiple of, and not less than, $1,000,000 (or, if less, the entire remaining amount of such Lender’s Commitment or Loans); provided that simultaneous assignments by two or more Related Funds shall be combined for purposes of determining whether the minimum assignment requirement is met, (ii) the parties to each assignment shall (A) execute and deliver to the Administrative Agent an Assignment and Acceptance via an electronic settlement system acceptable to the Administrative Agent or (B) if previously agreed with the Administrative Agent, manually execute and deliver to the Administrative Agent an Assignment and Acceptance, and, in each case, shall pay to the Administrative Agent a processing and recordation fee of $3,500 (which fee may be waived or reduced in the sole discretion of the Administrative Agent), and (iii) the assignee, if it shall not be a Lender, shall deliver to the Administrative Agent an Administrative Questionnaire (in which

 

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the assignee shall designate one or more credit contacts to whom all syndicate-level information (which may contain material non-public information about the Loan Parties and their Related Parties or their respective securities) will be made available and who may receive such information in accordance with the assignee’s compliance procedures and applicable laws, including Federal and state securities laws) and all applicable Tax forms required to be provided under Section 2.20(e). Upon acceptance and recording pursuant to paragraph (e) of this Section 9.04, from and after the effective date specified in each Assignment and Acceptance, (A) the assignee thereunder shall be a party hereto and, to the extent of the interest assigned by such Assignment and Acceptance, have the rights and obligations of a Lender under this Agreement and (B) the assigning Lender thereunder shall, to the extent of the interest assigned by such Assignment and Acceptance, be released from its obligations under this Agreement (and, in the case of an Assignment and Acceptance covering all or the remaining portion of an assigning Lender’s rights and obligations under this Agreement, such Lender shall cease to be a party hereto but, together with all related Indemnitees, shall continue to be entitled to the benefits of Sections 2.14, 2.16, 2.20 and 9.05, as well as to any Fees accrued for its account and not yet paid).

iii. By executing and delivering an Assignment and Acceptance, the assigning Lender thereunder and the assignee thereunder shall be deemed to confirm to and agree with each other and the other parties hereto as follows: (i) such assigning Lender warrants that it is the legal and beneficial owner of the interest being assigned thereby free and clear of any adverse claim, (ii) except as set forth in (i) above, such assigning Lender makes no representation or warranty and assumes no responsibility with respect to any statements, warranties or representations made in or in connection with this Agreement, or the execution, legality, validity, enforceability, genuineness, sufficiency or value of this Agreement, any other Loan Document or any other instrument or document furnished pursuant hereto, or the financial condition of the Borrower or the performance or observance by the Borrower or any Subsidiary of any of its obligations under this Agreement, any other Loan Document or any other instrument or document furnished pursuant hereto; (iii) such assignee represents and warrants that it is an Eligible Assignee legally authorized to enter into such Assignment and Acceptance; (iv) such assignee confirms that it has received a copy of this Agreement, together with copies of the most recent financial statements referred to in Section 3.05(a) or delivered pursuant to Section 5.05 and such other documents and information as it has deemed appropriate to make its own credit analysis and decision to enter into such Assignment and Acceptance; (v) such assignee will, independently and without reliance upon the Administrative Agent, the Collateral Agent, such assigning Lender or any other Lender and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under this Agreement; (vi) such assignee appoints and authorizes the Administrative Agent and the Collateral Agent to take such action as agent on its behalf and to exercise such powers under this Agreement as are delegated to the Administrative Agent and the Collateral Agent, respectively, by the terms hereof, together with such powers as are reasonably incidental thereto; and (vii) such assignee agrees that it will perform in accordance with their terms all the obligations which by the terms of this Agreement are required to be performed by it as a Lender.

iv. Notwithstanding Section 8.03, the Administrative Agent, acting solely for this purpose as an agent of the Borrower, shall maintain at one of its offices in The City of New York a copy of each Assignment and Acceptance delivered to it and a register for the recordation of

 

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the names and addresses of the Lenders, and the Commitment of, and principal amount of the Loans owing to, each Lender pursuant to the terms hereof from time to time (the “Register”). The entries in the Register shall be conclusive and the Borrower, the Administrative Agent, the Collateral Agent and the Lenders may treat each Person whose name is recorded in the Register pursuant to the terms hereof as a Lender hereunder for all purposes of this Agreement, notwithstanding notice to the contrary. The Register shall be available for inspection by the Borrower, the Collateral Agent and any Lender, at any reasonable time and from time to time upon reasonable prior notice.

v. Upon its receipt of, and consent to, a duly completed Assignment and Acceptance executed by an assigning Lender and an assignee, an Administrative Questionnaire completed in respect of the assignee (unless the assignee shall already be a Lender hereunder), the processing and recordation fee referred to in paragraph (b) above, if applicable, and the written consent of the Administrative Agent and, if required, the Borrower to such assignment and any applicable Tax forms required to be provided under Section 2.20(e), the Administrative Agent shall (i) accept such Assignment and Acceptance and (ii) record the information contained therein in the Register. No assignment shall be effective unless it has been recorded in the Register as provided in this paragraph (e).

vi. Each Lender may without the consent of the Borrower or the Administrative Agent sell participations to one or more banks or other Persons (other than a Disqualified Lender) (each, a “Participant”) in all or a portion of its rights and obligations under this Agreement (including all or a portion of its Commitment and the Loans owing to it); provided, however, that (i) such Lender’s obligations under this Agreement shall remain unchanged, (ii) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations and (iii) the Borrower, the Administrative Agent and the Lenders shall continue to deal solely and directly with such Lender in connection with such Lender’s rights and obligations under this Agreement, and such Lender shall retain the sole right to enforce the obligations of the Borrower relating to the Loans and to approve any amendment, modification or waiver of any provision of this Agreement (other than amendments, modifications or waivers decreasing any fees payable to such Participant hereunder or the amount of principal of or the rate at which interest is payable on the Loans in which such Participant has an interest, extending any scheduled principal payment date or date fixed for the payment of interest on the Loans in which such Participant has an interest, increasing or extending the Commitments in which such Participant has an interest or releasing all or substantially all of the value of the Guarantees of the Obligations or all or substantially all of the Collateral). The Borrower agrees that each Participant shall be entitled to the benefits of Sections 2.14, 2.16 and 2.20 (subject to the requirements and limitations therein, including the requirements under Section 2.20(e) (it being understood that the documentation required under Section 2.20(e) shall be delivered to the participating Lender)) to the same extent as if it were a Lender and had acquired its interest by assignment pursuant to paragraph (b) of this Section 9.04; provided that such Participant (A) agrees to be subject to the provisions of Section 2.21 as if it were an assignee under paragraph (b) of this Section 9.04; and (B) shall not be entitled to receive any greater payment under Section 2.14 or 2.20, with respect to any participation, than its participating Lender would have been entitled to receive, except to the extent such entitlement to receive a greater payment results from a Change in Law that occurs after the Participant acquired the applicable participation. To the extent permitted by law, each Participant also shall be entitled to the

 

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benefits of Section 9.06 as though it were a Lender, provided such Participant agrees to be subject to Section 2.18 as though it were a Lender. Each Lender that sells a participation shall, acting solely for this purpose as an agent of the Borrower, maintain a register on which it enters the name and address of each Participant and the principal amounts (and stated interest) of each Participant’s interest in the Loans or other obligations under the Loan Documents (the “Participant Register”); provided that no Lender shall have any obligation to disclose all or any portion of the Participant Register (including the identity of any Participant or any information relating to a Participant’s interest in any commitments, loans or its other obligations under any Loan Document) to any Person except to the extent that such disclosure is necessary to establish that such commitment, loan or other obligation is in registered form under Section 5f.103-1(c) of the United States Treasury Regulations. The entries in the Participant Register shall be conclusive absent manifest error, and such Lender shall treat each Person whose name is recorded in the Participant Register as the owner of such participation for all purposes of this Agreement notwithstanding any notice to the contrary. For the avoidance of doubt, the Administrative Agent (in its capacity as Administrative Agent) shall have no responsibility for maintaining a Participant Register. If the Borrower reasonably believes that a participation has been sold by a Lender to a Disqualified Lender, the applicable Lender shall provide (upon receipt of a written request from the Borrower) written confirmation to the Borrower either (1) confirming that no participations have been sold by such Lender to any Disqualified Lender or (2) identifying the applicable Disqualified Lender to which it has sold a participation.

vii. Any Lender or Participant may, in connection with any assignment or participation or proposed assignment or participation pursuant to this Section 9.04, disclose to the assignee or Participant or proposed assignee or participant any information relating to the Borrower furnished to such Lender by or on behalf of the Borrower; provided that, prior to any such disclosure of information designated by the Borrower as confidential, each such assignee or Participant or proposed assignee or Participant shall execute an agreement whereby such assignee or participant shall agree (subject to customary exceptions) to preserve the confidentiality of such confidential information on terms no less restrictive than those applicable to the Lenders pursuant to Section 9.16.

viii. Any Lender may at any time assign all or any portion of its rights under this Agreement to secure extensions of credit to such Lender or in support of obligations owed by such Lender; provided that no such assignment shall (i) release a Lender from any of its obligations hereunder or substitute any such assignee for such Lender as a party hereto or (ii) be permitted to be made to any Disqualified Lender.

ix. Notwithstanding anything to the contrary contained herein, any Lender (a “Granting Lender”) may grant to a special purpose funding vehicle (an “SPV”), identified as such in writing from time to time by the Granting Lender to the Administrative Agent and the Borrower, the option to provide to the Borrower all or any part of any Loan that such Granting Lender would otherwise be obligated to make to the Borrower pursuant to this Agreement; provided that (i) nothing herein shall constitute a commitment by any SPV to make any Loan and (ii) if an SPV elects not to exercise such option or otherwise fails to provide all or any part of such Loan, the Granting Lender shall be obligated to make such Loan pursuant to the terms hereof. The making of a Loan by an SPV hereunder shall utilize the Commitment of the Granting Lender to the same extent, and as if, such Loan were made by such Granting Lender.

 

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Each Granting Lender shall, acting solely for this purpose as an agent of the Borrower, maintain a register on which it enters the name and address of each SPV to which it grants an option pursuant to this Section 9.04(i) and the principal amounts (and stated interest) of any Loan or portion thereof provided to the Borrower by such SPV (the “SPV Register”); provided that no Lender shall have any obligation to disclose all or any portion of the SPV Register (including the identity of any SPV or any information relating to an SPV’s interest in any Commitments or Loans, or its other obligations under any Loan Document) to any Person except to the extent that such disclosure is necessary to establish that such Commitment, Loan or other obligation is in registered form under Section 5f.103-1(c) of the United States Treasury Regulations. The entries in the SPV Register shall be conclusive absent manifest error, and such Lender shall treat each Person whose name is recorded in the SPV Register as the owner of the relevant interest for all purposes of this Agreement notwithstanding any notice to the contrary. For the avoidance of doubt, the Administrative Agent (in its capacity as Administrative Agent) shall have no responsibility for maintaining any SPV Register. The Borrower agrees that each SPV shall be entitled to the benefits of Sections 2.14, 2.16 and 2.20 (subject to the requirements and limitations therein, including the requirements under Section 2.20(e) (it being understood that the documentation required under Section 2.20(e) shall be delivered to the Granting Lender)) to the same extent as if it were a Lender and had acquired its interest by assignment pursuant to paragraph (b) of this Section 9.04; provided that such SPV (A) agrees to be subject to the provisions of Section 2.21 as if it were an assignee under paragraph (b) of this Section 9.04; and (B) shall not be entitled to receive any greater payment under Section 2.14 or 2.20, with respect to any Loan, than its Granting Lender would have been entitled to receive, except to the extent such entitlement to receive a greater payment results from a Change in Law that occurs after the SPV acquired the applicable Loan. Each party hereto hereby agrees that no SPV shall be liable for any indemnity or similar payment obligation under this Agreement (all liability for which shall remain with the Granting Lender). In furtherance of the foregoing, each party hereto hereby agrees (which agreement shall survive the termination of this Agreement) that, prior to the date that is one year and one day after the payment in full of all outstanding commercial paper or other senior indebtedness of any SPV, it will not institute against, or join any other Person in instituting against, such SPV any bankruptcy, reorganization, arrangement, insolvency or liquidation proceedings under the laws of the United States or any State thereof. In addition, notwithstanding anything to the contrary contained in this Section 9.04, any SPV may (i) with notice to, but without the prior written consent of, the Borrower and the Administrative Agent and without paying any processing fee therefor, assign all or a portion of its interests in any Loans to the Granting Lender or to any financial institutions (consented to by the Borrower and Administrative Agent) providing liquidity and/or credit support to or for the account of such SPV to support the funding or maintenance of Loans and (ii) disclose on a confidential basis any non-public information relating to its Loans to any rating agency, commercial paper dealer or provider of any surety, guarantee or credit or liquidity enhancement to such SPV.

x. The Borrower shall not assign or delegate any of its rights or duties hereunder without the prior written consent of the Administrative Agent and each Lender, and any attempted assignment without such consent shall be null and void.

xi. Notwithstanding anything to the contrary contained in this Agreement, (i) any Lender may, at any time, assign all or any portion of its Loans to Holdings or the Borrower and (ii) Holdings and the Borrower may, from time to time, purchase Loans, in each case, on a non-

 

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pro rata basis through (x) Dutch auction procedures open to all Lenders on a pro rata basis in accordance with customary procedures to be agreed between the Borrower and the Administrative Agent or (y) open market purchases; provided that in connection with any assignment and purchase pursuant to this Section 9.04(k):

(A) no Event of Default shall have occurred and be continuing at the time of such assignment or shall result therefrom;

(B) any Loans purchased by Holdings or the Borrower shall, without further action by any Person, be deemed canceled and no longer outstanding (and may not be resold) for all purposes of this Agreement and all other Loan Documents, including, but not limited to (i) the making of, or the application of, any payments to the Lenders under this Agreement or any other Loan Document, (ii) the making of any request, demand, authorization, direction, notice, consent or waiver under this Agreement or any other Loan Document or (iii) the determination of Required Lenders (it being understood and agreed that (x) any gains or losses by the Borrower upon any such purchase and cancelation of Loans shall not be taken into account in the calculation of Excess Cash Flow, Consolidated Net Income and Consolidated EBITDAX and (y) any such purchase of Loans pursuant to this Section 9.04(k) shall not constitute a voluntary prepayment of Loans for purposes of this Agreement);

(C) Holdings or the Borrower, as applicable, shall not have any material non-public information that either (i) has not been disclosed in writing to the assigning Lender (other than any such Lender that does not wish to receive material non-public information) on or prior to the date of any assignment to Holdings or the Borrower or initiation of a Dutch auction by Holdings or the Borrower or (ii) if not disclosed to such Lender, could reasonably be expected to have a material effect upon, or otherwise be material to, (x) a Lender’s decision to make such assignment or (y) the market price of the Loans, in each case except to the extent that such Lender has entered into a customary “big boy” letter with Holdings or the Borrower, as applicable;

(D) the assigning Lender and Holdings or the Borrower, as applicable, shall execute and deliver to the Administrative Agent a Borrower Purchase Assignment and Acceptance in lieu of an Assignment and Acceptance; and

(E) the aggregate principal amount of Loans purchased by the Borrower and Holdings through open market purchases pursuant to this Section 9.04(k) shall not exceed $200,000,000 during the term of this Agreement.

In connection with any Loans purchased and canceled pursuant to this Section 9.04(k), the Administrative Agent is authorized to make appropriate entries in the Register to reflect any such cancelation.

 

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xii. (i) Notwithstanding anything to the contrary contained in this Agreement, any Lender may, at any time, assign all or any portion of its Loans to any Person who is or, after giving effect to such assignment, would be, an Affiliated Lender (without the consent of any Person but subject to acknowledgement by the Administrative Agent (which acknowledgement shall be provided promptly therefor) and the Borrower); provided that:

(A) the Affiliated Lender shall not have any material non-public information that either (i) has not been disclosed in writing to the assigning Lender (other than any such Lender that does not wish to receive material non-public information) on or prior to the date of any assignment to such Affiliated Lender or (ii) if not disclosed to such Lender, could reasonably be expected to have a material effect upon, or otherwise be material to, (x) a Lender’s decision to make such assignment or (y) the market price of the Loans, in each case except to the extent that such Lender has entered into a customary “big boy” letter with the Affiliated Lender, as applicable;

(B) the assigning Lender and the Affiliated Lender purchasing such Lender’s Loans shall execute and deliver to the Administrative Agent an Affiliated Lender Assignment and Acceptance in lieu of an Assignment and Acceptance; and

(C) after giving effect to such assignment, the aggregate principal amount of Loans held at any one time by Affiliated Lenders shall not exceed 25% of the aggregate principal amount of all Loans outstanding at such time under this Agreement.

Notwithstanding anything to the contrary in this Agreement, no Affiliated Lender shall have any right to (A) attend (including by telephone) any meeting or discussions (or portion thereof) (or receive notice of any such meetings or discussions) among the Administrative Agent and/or the Lenders to which representatives of the Loan Parties are not invited or (B) receive any information or materials prepared by the Administrative Agent or any Lender or any communication by or among the Administrative Agent and/or one or more Lenders, except to the extent such information or materials have been made available to any Loan Party or any representative of any Loan Party (and in any case, other than the right to receive notices of prepayments and other administrative notices in respect of its Loans).

Notwithstanding anything in Section 9.08 or the definition of “Required Lenders” to the contrary, for purposes of determining whether the Required Lenders, all affected Lenders or all Lenders have (A) consented (or not consented) to any amendment, modification, waiver, consent or other action with respect to any of the terms of any Loan Document or any departure by any Loan Party therefrom, (B) otherwise acted on any matter related to any Loan Document or (C) directed or required the Administrative Agent or any Lender to undertake any action (or refrain from taking any action) with respect to or under any Loan Document, an Affiliated Lender shall be deemed to have voted its interest as a Lender without discretion in the same proportion as the allocation of voting with respect to such matter by Lenders who are not Affiliated Lenders; provided that no amendment, modification, waiver, consent or other action with respect to any Loan Document shall deprive such Affiliated Lender of its pro rata share of any payments to which such Affiliated Lender is entitled under the Loan Documents without such Affiliated Lender providing its consent; provided, further, that such Affiliated Lender shall have the right to approve any amendment, modification, waiver or consent that (x) is of the type described in Sections 9.08(b)(i), 9.08(b)(ii) or 9.08(b)(iii) to the extent that such Affiliated Lender is directly and adversely affected thereby in its capacity as a Lender and (y) by its terms does not treat the Affiliated Lender on the same or better terms than any other Lender; and in

 

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furtherance of the foregoing the Affiliated Lender agrees to execute and deliver to the Administrative Agent any instrument reasonably requested by the Administrative Agent to evidence the voting of its interest as a Lender in accordance with the provisions of this Section 9.04(l).

Each Affiliated Lender, solely in its capacity as a Lender, hereby agrees, and each Affiliated Lender Assignment and Acceptance shall provide a confirmation that, if any Loan Party shall be subject to any bankruptcy proceeding, (A) such Affiliated Lender (in its capacity as such) shall not take any step or action in such bankruptcy proceeding to object to, impede, or delay the exercise of any right or the taking of any action by the Administrative Agent (or the taking of any action by a third party that is supported by the Administrative Agent) in relation to such Affiliated Lender’s claim with respect to its Loans (a “Claim”) (including objecting to any debtor in possession financing, use of cash collateral, grant of adequate protection, sale or disposition, compromise, or plan of reorganization) so long as such Affiliated Lender is treated in connection with such exercise or action on the same or better terms as the other Lenders and (B) with respect to any matter requiring the vote of Lenders during the pendency of a bankruptcy proceeding (including voting on any plan of reorganization), the Loans held by such Affiliated Lender (and any Claim with respect thereto) shall be deemed to be voted in accordance with clause (iii) above, so long as such Affiliated Lender is treated in connection with the exercise of such right or taking of such action on the same or better terms as the other Lenders. For the avoidance of doubt, the Lenders and each Affiliated Lender agree and acknowledge that the provisions set forth in this clause (iv), and the related provisions set forth in each Affiliated Lender Assignment and Acceptance, constitute a “subordination agreement” as such term is contemplated by, and utilized in, Section 510(a) of the United States Bankruptcy Code, and, as such, would be enforceable for all purposes in any case where a Loan Party has filed for protection under any Debtor Relief Law applicable to such Loan Party.

xiii. The Lenders hereby consent to the transactions described in Sections 9.04(k) and (l) and acknowledge that purchases made by Holdings or the Borrower pursuant to Section 9.04(k) may result in the retirement of Loans on a non-pro rata basis among the Lenders. The Lenders further acknowledge that any payment made to a Lender in connection with a transaction described in Section 9.04(k) or (l) is solely for the account of such Lender and no ratable sharing of such proceeds is required under this Agreement or any other Loan Document.

xiv. Notwithstanding anything else to the contrary in this Section 9.04 or this Agreement, each of the parties hereto acknowledges and agrees that the Administrative Agent (x) shall not have any responsibility or obligation to determine whether any Lender or any potential assignee is a Disqualified Lender and (y) shall not have any liability with respect to any assignment or participation made to, or information shared with, a Disqualified Lender.

E. Expenses; Indemnity. i. The Borrower agrees to pay (1) all reasonable, documented and invoiced out-of-pocket expenses incurred by the Administrative Agent and the Collateral Agent in connection with the syndication of the Credit Facility and the preparation and administration of this Agreement and the other Loan Documents or in connection with any amendments, modifications or waivers of the provisions hereof or thereof (whether or not the transactions hereby or thereby contemplated shall be consummated), including the reasonable and documented fees, charges and disbursements of Cravath, Swaine & Moore LLP, counsel for

 

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the Administrative Agent and the Collateral Agent and reasonably necessary special counsel (and, if necessary, by a firm of local counsel in each relevant jurisdiction and in the case of an actual or reasonably perceived conflict of interest, one additional firm of counsel to the affected Lenders), and (2) all reasonable, documented and invoiced out-of-pocket expenses incurred by the Administrative Agent, the Collateral Agent or any Lender in connection with the enforcement or protection of its rights in connection with this Agreement and the other Loan Documents or in connection with the Loans made hereunder, and, in connection with any such enforcement or protection, the reasonable fees, charges and disbursements of one counsel and reasonably necessary special counsel (and, if necessary, a firm of local counsel in each relevant jurisdiction and in the case of an actual or reasonably perceived conflict of interest, one additional firm of counsel to each group of similarly affected Lenders (or the Administrative Agent or Collateral Agent, if applicable)).

ii. The Borrower agrees to indemnify the Arrangers, the Administrative Agent, the Collateral Agent, each Lender and each Related Party of any of the foregoing Persons (each such Person being called an “Indemnitee”) against, and to hold each Indemnitee harmless from, any and all losses, claims, damages, liabilities and related expenses, including reasonable, documented and invoiced counsel fees, charges and disbursements (such counsel to be limited to one firm of counsel for all Indemnitees taken as a whole, and reasonably necessary special counsel for all Indemnitees taken as a whole (and, if necessary, one firm of local counsel in each relevant jurisdiction for all such Indemnitees taken as a whole) and, in the case of an actual or reasonably perceived conflict of interest where the Indemnitee or Indemnitees affected by such conflict informs the Borrower of such conflict, one additional counsel and reasonably necessary special counsel to each group of similarly affected Indemnitees taken as a whole (and, if necessary, one firm of local counsel in each relevant jurisdiction to each such group of similarly affected Indemnitees), incurred by or asserted against any Indemnitee arising out of, in any way connected with, or as a result of (i) the execution or delivery of this Agreement or any other Loan Document or any agreement or instrument contemplated thereby, the performance by the parties thereto of their respective obligations thereunder or the consummation of the Transactions and the other transactions contemplated thereby (including the syndication of the Credit Facility), (ii) the use of the proceeds of the Loans, (iii) any claim, litigation, investigation or proceeding relating to any of the foregoing, whether or not any Indemnitee is a party thereto (and regardless of whether such matter is initiated by a third party or by the Borrower, any other Loan Party or any of their respective Affiliates), or (iv) any actual or alleged presence or Release of Hazardous Materials on any property currently or formerly owned or operated by the Borrower or any of the Subsidiaries, or any other Environmental Liability related in any way to the Borrower or the Subsidiaries; provided that such indemnity shall not (x) as to any Indemnitee, be available to the extent that such losses, claims, damages, liabilities or related expenses are determined by a court of competent jurisdiction by final and non-appealable judgment to have resulted from the willful misconduct, bad faith or gross negligence of such Indemnitee or any of such Indemnitee’s officers or employees or (y) be available in respect of any proceeding not arising out of an act or omission by the Borrower or its affiliates that is brought by an Indemnitee against any other Indemnitee (other than disputes involving claims against the Administrative Agent or any Arranger (or any of their respective Affiliates) in their respective capacities or in fulfilling their roles as such or any other similar role with respect to this Agreement and the Credit Facility to the extent such Person is otherwise entitled to indemnification hereunder). This Section 9.05(b) shall not apply with respect to Taxes other than any Taxes that represent losses, claims, or damages arising from any non-Tax claims.

 

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iii. To the extent that the Borrower fails to pay any amount required to be paid by it to the Administrative Agent or the Collateral Agent under paragraph (a) or (b) of this Section, each Lender severally agrees to pay to the Administrative Agent or the Collateral Agent, as the case may be, such Lender’s pro rata share (determined as of the time that the applicable unreimbursed expense or indemnity payment is sought) of such unpaid amount; provided that the unreimbursed expense or indemnified loss, claim, damage, liability or related expense, as the case may be, was incurred by or asserted against the Administrative Agent or the Collateral Agent in its capacity as such. For purposes hereof, a Lender’s “pro rata share” shall be determined based upon its share of outstanding Loans (in each case, determined as if no Lender were a Defaulting Lender).

iv. To the extent permitted by applicable law, the Borrower shall not assert, and hereby waives, any claim against any Indemnitee, on any theory of liability, for special, indirect, consequential or punitive damages (as opposed to direct or actual damages) arising out of, in connection with, or as a result of, this Agreement or any agreement or instrument contemplated hereby, the Transactions or any Loan or the use of the proceeds thereof.

v. The provisions of this Section 9.05 shall remain operative and in full force and effect regardless of the expiration of the term of this Agreement, the consummation of the Transactions and the other transactions contemplated hereby, the repayment of any of the Loans, the expiration of the Commitments, the invalidity or unenforceability of any term or provision of this Agreement or any other Loan Document, or any investigation made by or on behalf of the Administrative Agent, the Collateral Agent or any Lender. All amounts due under this Section 9.05 shall be payable within ten days following written demand therefor.

F. Right of Setoff. If an Event of Default shall have occurred and be continuing, each Lender is hereby authorized at any time and from time to time, except to the extent prohibited by law, to set off and apply any and all deposits (general or special, time or demand, provisional or final) at any time held and other indebtedness at any time owing by such Lender to or for the credit or the account of the Borrower against any of and all the obligations of the Borrower now or hereafter existing under this Agreement and other Loan Documents held by such Lender, irrespective of whether or not such Lender shall have made any demand under this Agreement or such other Loan Document and although such obligations may be unmatured. The rights of each Lender under this Section 9.06 are in addition to other rights and remedies (including other rights of setoff) which such Lender may have.

G. Applicable Law. THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS (OTHER THAN AS EXPRESSLY SET FORTH IN OTHER LOAN DOCUMENTS) SHALL BE CONSTRUED IN ACCORDANCE WITH AND GOVERNED BY THE LAWS OF THE STATE OF NEW YORK.

H. Waivers; Amendment. i. No failure or delay of the Administrative Agent, the Collateral Agent or any Lender in exercising any power or right hereunder or under any other Loan Document shall operate as a waiver thereof, nor shall any single or partial exercise of any

 

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such right or power, or any abandonment or discontinuance of steps to enforce such a right or power, preclude any other or further exercise thereof or the exercise of any other right or power. The rights and remedies of the Administrative Agent, the Collateral Agent and the Lenders hereunder and under the other Loan Documents are cumulative and are not exclusive of any rights or remedies that they may otherwise have. No waiver of any provision of this Agreement or any other Loan Document or consent to any departure by the Borrower or any other Loan Party therefrom shall in any event be effective unless the same shall be permitted by paragraph (b) below, and then such waiver or consent shall be effective only in the specific instance and for the purpose for which given. No notice or demand on the Borrower in any case shall entitle the Borrower to any other or further notice or demand in similar or other circumstances.

ii. Neither this Agreement nor any provision hereof may be waived, amended or modified except pursuant to an agreement or agreements in writing entered into by the Borrower, the Administrative Agent and the Required Lenders; provided, however, that no such agreement shall (i) decrease the principal amount of, or extend the maturity of or any scheduled principal payment date or date for the payment of any interest on any Loan, or waive or excuse any such payment or any part thereof, or decrease the rate of interest on any Loan, without the prior written consent of each Lender directly affected thereby, it being understood that (x) the waiver of (or amendment to the terms of) any mandatory prepayment of the Loans shall not constitute a postponement of any date scheduled for the payment of principal or interest and (y) only the consent of the Required Lenders shall be necessary to waive any obligation of the Borrower to pay interest pursuant to Section 2.07, (ii) increase or extend the Commitment or decrease the amount of (it being understood that a waiver of any condition precedent set forth in Section 4.01 or the waiver of any Default or mandatory prepayment shall not constitute an extension or increase of any Commitment of any Lender), or extend the date for, payment of any Fees or Applicable Premium of any Lender without the prior written consent of such Lender, (iii) amend or modify the pro rata requirements of Section 2.17, the provisions of Section 9.04(j) or the provisions of this Section or (other than in a transaction permitted under Section 6.05) release all or substantially all of the value of the Guarantees or all or substantially all of the Collateral, without the prior written consent of each Lender, (iv) modify the protections afforded to an SPV pursuant to the provisions of Section 9.04(i) without the written consent of such SPV or (v) amend or modify the percentage contained in the definition of the term “Required Lenders” without the prior written consent of each Lender; provided further that no such agreement shall amend, modify or otherwise affect the rights or duties of the Administrative Agent or the Collateral Agent hereunder or under any other Loan Document without the prior written consent of the Administrative Agent or the Collateral Agent. No Secured Party shall have any voting rights under this Agreement or any other Loan Document as a result of (a) the existence of obligations owed to it under Hedging Agreements or Cash Management Agreements or (b) its being a beneficiary of the indemnification obligations undertaken by any Loan Party hereunder or thereunder.

iii. The Administrative Agent and the Borrower may amend any Loan Document to correct administrative errors or omissions, or to effect administrative changes that are not adverse to any Lender. Notwithstanding anything to the contrary contained herein, such amendment shall become effective without any further consent of any other party to such Loan Document.

 

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I. Interest Rate Limitation. Notwithstanding any provision herein to the contrary, if at any time the interest rate applicable to any Loan, together with all fees, charges and other amounts which are treated as interest on such Loan under applicable law (collectively, the “Charges”) shall exceed the maximum lawful rate (the “Maximum Rate”) which may be contracted for, charged, taken, received or reserved by the Lender holding such Loan in accordance with applicable law, the rate of interest payable in respect of such Loan hereunder, together with all Charges payable in respect thereof, shall be limited to the Maximum Rate and, to the extent lawful, the interest and Charges that would have been payable in respect of such Loan but were not payable as a result of the operation of this Section 9.09 shall be cumulated and the interest and Charges payable to such Lender in respect of other Loans or periods shall be increased (but not above the Maximum Rate therefor) until such cumulated amount, together with interest thereon at the Federal Funds Effective Rate to the date of repayment, shall have been received by such Lender.

J. Entire Agreement. This Agreement, the other Loan Documents and any written agreement regarding the payment of Fees constitute the entire contract between the parties relative to the subject matter hereof. Any other previous agreement among the parties with respect to the subject matter hereof is superseded by this Agreement and the other Loan Documents. Nothing in this Agreement or in the other Loan Documents, expressed or implied, is intended to confer upon any Person (other than the parties hereto and thereto, their respective successors and assigns permitted hereunder and, to the extent expressly contemplated hereby, the Arrangers and the Related Parties of each of the Administrative Agent, the Collateral Agent, the Arrangers and the Lenders and the other Secured Parties) any rights, remedies, obligations or liabilities under or by reason of this Agreement or the other Loan Documents.

K. WAIVER OF JURY TRIAL. EACH PARTY HERETO HEREBY WAIVES, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY RIGHT IT MAY HAVE TO A TRIAL BY JURY IN RESPECT OF ANY LITIGATION DIRECTLY OR INDIRECTLY ARISING OUT OF, UNDER OR IN CONNECTION WITH THIS AGREEMENT OR ANY OF THE OTHER LOAN DOCUMENTS. EACH PARTY HERETO (A) CERTIFIES THAT NO REPRESENTATIVE, AGENT OR ATTORNEY OF ANY OTHER PARTY HAS REPRESENTED, EXPRESSLY OR OTHERWISE, THAT SUCH OTHER PARTY WOULD NOT, IN THE EVENT OF LITIGATION, SEEK TO ENFORCE THE FOREGOING WAIVER AND (B) ACKNOWLEDGES THAT IT AND THE OTHER PARTIES HERETO HAVE BEEN INDUCED TO ENTER INTO THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS, AS APPLICABLE, BY, AMONG OTHER THINGS, THE MUTUAL WAIVERS AND CERTIFICATIONS IN THIS SECTION 9.11.

L. Severability. In the event any one or more of the provisions contained in this Agreement or in any other Loan Document should be held invalid, illegal or unenforceable in any respect, the validity, legality and enforceability of the remaining provisions contained herein and therein shall not in any way be affected or impaired thereby (it being understood that the invalidity of a particular provision in a particular jurisdiction shall not in and of itself affect the validity of such provision in any other jurisdiction). The parties shall endeavor in good-faith negotiations to replace the invalid, illegal or unenforceable provisions with valid provisions the economic effect of which comes as close as possible to that of the invalid, illegal or unenforceable provisions.

 

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M. Counterparts. This Agreement may be executed in counterparts (and by different parties hereto on different counterparts), each of which shall constitute an original but all of which when taken together shall constitute a single contract, and shall become effective as provided in Section 9.03. Delivery of an executed signature page to this Agreement by facsimile or other electronic transmission shall be as effective as delivery of a manually signed counterpart of this Agreement.

N. Headings. Article and Section headings and the Table of Contents used herein are for convenience of reference only, are not part of this Agreement and are not to affect the construction of, or to be taken into consideration in interpreting, this Agreement.

O. Jurisdiction; Consent to Service of Process. i. The Borrower hereby irrevocably and unconditionally submits, for itself and its property, to the exclusive jurisdiction of any New York State court or Federal court of the United States of America sitting in New York City, and any appellate court from any thereof, in any action or proceeding arising out of or relating to this Agreement or the other Loan Documents, or for recognition or enforcement of any judgment, and each of the parties hereto hereby irrevocably and unconditionally agrees that all claims in respect of any such action or proceeding may be heard and determined in such New York State or, to the extent permitted by law, in such Federal court. Each of the parties hereto agrees that a final judgment in any such action or proceeding shall be conclusive and may be enforced in other jurisdictions by suit on the judgment or in any other manner provided by law. Nothing in this Agreement shall affect any right that the Administrative Agent, the Collateral Agent or any Lender may otherwise have to bring any action or proceeding relating to this Agreement or the other Loan Documents against the Borrower or its properties in the courts of any jurisdiction.

ii. The Borrower hereby irrevocably and unconditionally waives, to the fullest extent it may legally and effectively do so, any objection which it may now or hereafter have to the laying of venue of any suit, action or proceeding arising out of or relating to this Agreement or the other Loan Documents in any New York State or Federal court. Each of the parties hereto hereby irrevocably waives, to the fullest extent permitted by law, the defense of an inconvenient forum to the maintenance of such action or proceeding in any such court.

iii. Each party to this Agreement irrevocably consents to service of process in the manner provided for notices in Section 9.01. Nothing in this Agreement will affect the right of any party to this Agreement to serve process in any other manner permitted by law.

P. Confidentiality. Each of the Administrative Agent, the Collateral Agent and the Lenders agrees to maintain the confidentiality of the Information (as defined below), except that Information may be disclosed (a) to its and its Affiliates’ officers, directors, employees and agents, including accountants, legal counsel and other advisors (it being understood that the Persons to whom such disclosure is made will be informed of the confidential nature of such Information and instructed to keep such Information confidential), (b) to the extent requested by any regulatory authority or quasi-regulatory authority (such as the National Association of Insurance Commissioners) (subject to prompt notice to the Borrower thereof to the extent not prohibited by law, rule or regulation prior to disclosure), (c) to the extent required by applicable laws or regulations or by any subpoena or similar compulsory legal process (subject to prompt

 

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notice to the Borrower thereof to the extent not prohibited by law, rule or regulation prior to disclosure), (d) in connection with the exercise of any remedies hereunder or under the other Loan Documents or any suit, action or proceeding relating to the enforcement of its rights hereunder or thereunder, (e) subject to an agreement containing provisions substantially the same as those of this Section 9.16, to (i) any actual or prospective assignee of or Participant in (in each case, other than a Disqualified Lender) any of its rights or obligations under this Agreement and the other Loan Documents or (ii) any actual or prospective counterparty (or its advisors) to any swap or derivative transaction relating to the Borrower or any Subsidiary or any of their respective obligations (in each case, other than a Disqualified Lender) as designated by the Borrower, (f) on a confidential basis to (i) any rating agency in connection with rating the Borrower or any of its respective Subsidiaries or the Credit Facility hereunder, (ii) the CUSIP Service Bureau or any similar agency in connection with the issuance and monitoring of CUSIP numbers with respect to the facilities or (iii) market data collectors, similar service providers to the lending industry and service providers to the Administrative Agent in connection with the administration, settlement and management of this Agreement and the Loan Documents, (g) with the consent of the Borrower or (h) to the extent such Information becomes publicly available other than as a result of a breach of this Section 9.16. For the purposes of this Section, “Information” shall mean all information received from the Borrower and related to the Borrower or its business, other than any such information that was available to the Administrative Agent, the Collateral Agent or any Lender on a nonconfidential basis prior to its disclosure by the Borrower; provided that, in the case of Information received from the Borrower after the date hereof, such information is clearly identified at the time of delivery as confidential. For the avoidance of doubt, in no event shall any disclosure of Information be made to any Disqualified Lender. Any Person required to maintain the confidentiality of Information as provided in this Section 9.16 shall be considered to have complied with its obligation to do so if such Person has exercised the same degree of care to maintain the confidentiality of such Information as such Person would accord its own confidential information.

Q. Lender Action. Each Lender agrees that it shall not take or institute any actions or proceedings, judicial or otherwise, for any right or remedy against any Loan Party or any other obligor under any of the Loan Documents (including the exercise of any right of setoff, rights on account of any banker’s lien or similar claim or other rights of self-help), or institute any actions or proceedings, or otherwise commence any remedial procedures, with respect to any Collateral or any other property of any such Loan Party, unless expressly provided for herein or in any other Loan Document, without the prior written consent of the Administrative Agent or the Collateral Agent, as applicable. The provisions of this Section 9.17 are for the sole benefit of the Administrative Agent, the Collateral Agent and the Lenders and shall not afford any right to, or constitute a defense available to, any Loan Party.

R. USA PATRIOT Act Notice. Each Lender and the Administrative Agent (for itself and not on behalf of any Lender) hereby notifies the Borrower that pursuant to the requirements of the USA PATRIOT Act, it is required to obtain, verify and record information that identifies the Borrower and the Guarantors, which information includes the name and address of the Borrower and each Guarantor and other information that will allow such Lender or the Administrative Agent, as applicable, to identify the Borrower and the Guarantors in accordance with the USA PATRIOT Act.

 

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S. [Reserved].

T. Secured Hedging Agreements. For the avoidance of doubt, no Person that is a Secured Party hereunder pursuant to clause (d) of the definition of “Secured Party” (for purposes of this Section 9.20, a “Secured Hedge Provider”) and obtains the benefits of (x) Section 7.04 of the Guarantee and Collateral Agreement, (y) the guarantee provided for therein or (z) the Collateral by virtue of the provisions hereof or any Security Document shall have any right to notice of any action or to consent to, direct or object to any action hereunder or under any other Loan Document or otherwise in respect of the Collateral (including the release or impairment of any Collateral) other than in its capacity as a Lender. Notwithstanding any other provision of Article VIII to the contrary, the Administrative Agent shall not be required to verify the payment of, or that other satisfactory arrangements have been made with respect to, Obligations arising under Hedging Agreements between a Loan Party and a Secured Hedge Provider unless the Administrative Agent has received written notice of such Obligations, together with such supporting documentation as the Administrative Agent may request, from the applicable Secured Hedge Provider and the Borrower.

[Signature pages immediately follow]

 

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IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed by their respective authorized officers as of the day and year first above written.

 

ENERGY & EXPLORATION PARTNERS, LLC
By:  

/s/ B. Hunt Pettit

Name:   B. Hunt Pettit
Title:   President and CEO

SOLELY WITH RESPECT TO SECTION 6.21,

ENERGY & EXPLORATION PARTNERS, INC.

By:  

/s/ B. Hunt Pettit

Name:   B. Hunt Pettit
Title:   President and CEO


CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH, as Administrative Agent, Collateral

Agent and a Lender

By:  

/s/ Nupur Kumar

Name:   Nupur Kumar
Title:   Authorized Signatory
By:  

/s/ Michael Spaight

Name:   Michael Spaight
Title:   Authorized Signatory

[Signature Page – Credit Agreement]


Schedule 1.01(a)

Subsidiary Guarantors

Energy & Exploration Partners Operating, LP, a Texas limited partnership

Energy & Exploration Partners Operating GP, LLC, a Texas limited liability company


Schedule 1.01(b)

Material Contracts

Purchase and Sale Agreement

 

  1. Purchase and Sale Agreement dated August 23, 2012 by and between Energy & Exploration Partners, LLC and CEU Huntsville, LLC as amended by the First Amendment to Purchase and Sale Agreement dated September 28, 2012 by and between Energy & Exploration Partners, LLC and CEU Huntsville, LLC.

 

  2. Purchase and Sale Agreement dated June 13, 2014 by and between TreadStone Energy Partners, LLC, as seller, and Energy & Exploration Partners, LLC, as buyer.

Other

 

  1. Letter Agreement dated June 26, 2012, among Petro Capital XXV, LLC, Energy & Exploration Partners, LLC, Energy & Exploration Partners, LP and North American Shale Investment Fund, LP.

 

  2. Equity Kicker Letter dated as of June 26, 2012 among the Energy & Exploration Partners, LLC and Guggenheim Corporate Funding, LLC amended by First Amendment to Equity Kicker Letter dated July 11, 2012 among the Energy & Exploration Partners, LLC and Guggenheim Corporate Funding, LLC.


Schedule 2.01

Lenders and Commitments

 

Lender

   Commitment  

Credit Suisse AG, Cayman Islands Branch

   $ 775,000,000   

TOTAL

   $ 775,000,000   


Schedule 3.08

Subsidiaries

A. Exact legal name of each Subsidiary.

Energy & Exploration Partners Operating, LP

Energy & Exploration Partners Operating GP, LLC

B. Ownership percentage of each Loan Party.

1) Ownership of Energy & Exploration Partners Operating, LP

Energy & Exploration Partners, LLC is a limited partner of Energy & Exploration Partners Operating, LP (99%).

Energy & Exploration Partners Operating GP, LLC is the general partner of Energy & Exploration Partners Operating, LP (1%).

2) Ownership of Energy & Exploration Partners Operating GP, LLC

Energy & Exploration Partners, LLC is the sole member of Energy & Exploration Partners Operating GP, LLC (100%).

C. Jurisdiction of organization of each Subsidiary.

Energy & Exploration Partners Operating GP, LLC - Texas

Energy & Exploration Partners Operating, LP - Texas

D. Chief executive office for all Subsidiaries.

Two City Place, 100 Throckmorton, Suite 1700, Fort Worth, Texas 76102


Schedule 3.09

Litigation

None.


Schedule 3.14

Payment of Taxes

Taxes owed with respect to Holdings’ 2012 Federal Income Tax Return. The estimated amount of federal taxes payable by Holding’s consolidated group for 2012 is approximately $0.322 million excluding interest and penalties. On or about September 15, 2013, Holdings timely filed its 2012 Federal Income Tax Return, which showed such amount is due but it did not pay the taxes shown as due on the return because Holdings planned to net its 2012 taxable income against the net operating losses that it anticipated generating during its 2013 tax year. Holdings generated $39.3 million in net operating losses for 2013, which is sufficiently large enough to fully offset the 2012 taxable income for regular tax purposes but anticipates that annual limitations on the ability to carry back alternative minimum tax losses will leave approximately $0.322 million in balance due related to AMT or Alternative Minimum Tax. Near the end of 2013, Holdings was contacted by the IRS regarding the status of its 2012 tax payment. Holdings’ tax advisor informed the IRS that Holdings plans to net its 2012 taxable income against its 2013 net operating losses. Holdings is unaware of anything that may prevent Holdings from such offset, and to Holdings’ knowledge, the IRS has not disputed the amount shown on the 2012 tax returns. On February 7, 2013, the IRS granted Holdings a hold until April 7, 2014 on collection efforts and during 2014 additional extensions of time have been granted. Holdings filed its 2013 tax return as well as its carry back claim during the last week of May 2014 in order to offset the balance of regular tax due on its 2012 return and the IRS is currently processing the return information and has granted an additional extension of time while it processes the return information. Holdings expects that the total interest and penalties with respect to the 2012 tax returns to be $1.75 million as of March 31, 2014. Holdings has previously paid $500,000 of this total to the IRS, and it will request a waiver of the penalty for approximately $475,000, but there is no guarantee that the waiver will be granted. In the event that the waiver is fully denied, Holdings will pay an additional $1.25 million for interest and penalties with respect to its 2012 returns. If the waiver is fully granted it will pay an additional $775,000 for interest with respect to its 2012 returns. The failure to make either payment will not result in a Material Adverse Effect.


Schedule 3.17

Environmental Matters

None.


Schedule 3.18

Insurance

[See Attached]


Schedule 3.19(a)

Filing Offices

Filing of UCC-1 Financing Statements with respect to the Collateral with the Secretary of State of the state set forth below opposite each Loan Party’s name:

 

Loan Party

   State(s)

Energy & Exploration Partners, Inc.

   Delaware

Energy & Exploration Partners, LLC

   Delaware

Energy & Exploration Partners Operating, LP

   Texas

Energy & Exploration Partners Operating GP, LLC

   Texas


Schedule 3.19(b)

Mortgage Filing Offices

Grimes County, Texas

Leon County, Texas

Madison County, Texas

Houston County, Texas


Schedule 3.24

Marketing Contracts

Gas Gathering Contract (North Zulch) dated January 1, 2012 between Chesapeake Energy Marketing, Inc., Chesapeake Operating, Inc., and Chesapeake Exploration L.L.C., collectively as Producer, and Texas Midstream Gas Services, L.L.C., as Gatherer

Gas Purchase and Gas Processing Contract dated June 1, 2011 between ETC Texas Pipeline, LTD. and Chesapeake Energy Marketing, Inc. and Chesapeake Exploration L.L.C.

Individual Transaction Confirmation to Gas Purchase and Gas Processing Contract Between Chesapeake Energy Marketing, Inc., Chesapeake Exploration, L.L.C. and ETC Texas Pipeline, LTD. dated June 1, 2011

Amendment to Gas Purchase and Gas Processing Contract and Individual Transaction Confirmation effective August 1, 2013 by ETC Texas Pipeline, Ltd., Energy & Exploration Partners LLC, and SEI Energy, LLC.

Amendment to Individual Transaction Confirmation effective January 1, 2014 by ETC Texas Pipeline, Ltd., Energy & Exploration Partners LLC, and SEI Energy, LLC

Individual Transaction Confirmation to Gas Purchase and Gas Processing Contract between SEI Energy, LLC, Energy & Exploration Partners, LLC and ETC Texas Pipeline, LTD. dated November 1, 2013

Gas Gathering Agreement by and between Halcón Field Services, LLC, Energy and Exploration Partners, LLC and SEI Energy, LLC effective November 1, 2013

Gas Gathering Contract between Energy & Exploration Partners, LLC, SEI Energy, LLC and BSR Gas Marketing, Ltd. effective October 4, 2013

Gas Gathering Processing & Marketing Agreement dated November 7, 2012, by and between Canyon Midstream Partners, LLC and TreadStone Energy Partners, LLC.


Schedule 3.25

Hedging Agreements

 

Trade
Date

   Underlying    Market    Trade
Type
   Price      Strike      Qty
Rate
     Units      Qty
Frequency
     Total
Qty
     Start
Date
     End Date      Counterparty    Settled      Margin  

30-Oct-13

   Argus LLS    Crude    Fixed Swap      97.5            -100         bbl         calendar day         -36,500         1-Jan-14         31-Dec-14       BP      Monthly         None   

4-Nov-13

   Argus LLS    Crude    Fixed Swap      95.15            -150         bbl         calendar day         -54,750         1-Jan-14         31-Dec-14       BP      Monthly         None   

5-Nov-13

   Argus LLS    Crude    Fixed Swap      95.2            -150         bbl         calendar day         -54,750         1-Jan-14         31-Dec-14       BP      Monthly         None   

6-Dec-13

   Argus LLS    Crude    Fixed Swap      98.15            -100         bbl         calendar day         -36,500         1-Jan-14         31-Dec-14       Macquarie      Monthly         None   

30-Oct-13

   Argus LLS    Crude    Asian Floor      0         82         100         bbl         calendar day         36,500         1-Jan-15         31-Dec-15       BP      Monthly         None   

30-Oct-13

   Argus LLS    Crude    Asian Cap      0         99.6         -100         bbl         calendar day         -36,500         1-Jan-15         31-Dec-15       BP      Monthly         None   

4-Nov-13

   Argus LLS    Crude    Asian Floor      0         80         100         bbl         calendar day         36,500         1-Jan-15         31-Dec-15       BP      Monthly         None   

4-Nov-13

   Argus LLS    Crude    Asian Cap      0         97.25         -100         bbl         calendar day         -36,500         1-Jan-15         31-Dec-15       BP      Monthly         None   

31-Oct-13

   Argus LLS    Crude    Asian Floor      0         72         100         bbl         calendar day         36,600         1-Jan-16         31-Dec-16       BP      Monthly         None   

31-Oct-13

   Argus LLS    Crude    Asian Cap      0         101.6         -100         bbl         calendar day         -36,600         1-Jan-16         31-Dec-16       BP      Monthly         None   

4-Nov-13

   Argus LLS    Crude    Asian Floor      0         71.5         100         bbl         calendar day         36,600         1-Jan-16         31-Dec-16       BP      Monthly         None   

4-Nov-13

   Argus LLS    Crude    Asian Cap      0         99.25         -100         bbl         calendar day         -36,600         1-Jan-16         31-Dec-16       BP      Monthly         None   

19-Feb-14

   NYMEX WTI    Crude    Fixed Swap      95.55            -150         bbl         calendar day         -27,600         1-Jul-14         31-Dec-14       BP      Monthly         None   

10-Feb-14

   NYMEX    N. Gas    Fixed Swap      4.44            -500         MMbtu         calendar day         -153,000         1-Mar-14         31-Dec-14       BP      Monthly         None   

10-Feb-14

   NYMEX    N. Gas    Asian Floor      0         78         150         bbl            54,750         1-Jan-15         31-Dec-15       BP      Monthly         None   

10-Feb-14

   NYMEX    N. Gas    Asian Cap      0         96.1         -150               -54,750         1-Jan-15         31-Dec-15       BP      Monthly         None   


Schedule 3.26

Gas Balancing Agreements

None.


Schedule 6.01

Existing Indebtedness

None.


Schedule 6.02

Existing Liens

None.


Schedule 6.07

Restrictive Agreements

None.


Schedule 6.08

Affiliate Transactions

None.


 

 

EXHIBITS

to

CREDIT AGREEMENT

by and among

Energy & Exploration Partners, Inc.,

as Holdings,

Energy & Exploration Partners, LLC,

as Borrower,

the Lenders party thereto

and

Credit Suisse AG, Cayman Islands Branch,

as Administrative Agent and Collateral Agent

dated as of

July 22, 2014

 

 

 


Exhibit A-1

to the Credit Agreement

FORM OF ASSIGNMENT AND ACCEPTANCE

This Assignment and Acceptance (the “Assignment”) is dated as of the Effective Date set forth below and is entered into by and between [Insert name of Assignor] (the “Assignor”) and [Insert name of Assignee] (the “Assignee”). Capitalized terms used but not defined herein shall have the meanings given to them in the Credit Agreement identified below (as amended, the “Credit Agreement”), receipt of a copy of which is hereby acknowledged by the Assignee. The Standard Terms and Conditions set forth in Annex 1 attached hereto are hereby agreed to and incorporated herein by reference and made a part of this Assignment as if set forth herein in full.

For an agreed consideration, the Assignor hereby irrevocably sells and assigns to the Assignee, and the Assignee hereby irrevocably purchases and assumes from the Assignor, subject to and in accordance with the Standard Terms and Conditions and the Credit Agreement, as of the Effective Date inserted by Administrative Agent as contemplated below, the interest in and to all of the Assignor’s rights and obligations under the Credit Agreement and any other documents or instruments delivered pursuant thereto that represents the amount and percentage interest identified below of all of the Assignor’s outstanding rights and obligations under the Credit Agreement (the “Assigned Interest”). Such sale and assignment is without recourse to the Assignor and, except as expressly provided in this Assignment, without representation or warranty by the Assignor.

 

1.        Assignor:                                                                                                                                                                                          
2.    Assignee:                                                                                         [is a[n] [Lender/Affiliate of a Lender/Related Fund of a Lender]]1
3.    Borrower:    Energy & Exploration Partners, LLC
4.    Administrative Agent:    CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH, as Administrative Agent under the Credit Agreement
5.    Credit Agreement    Credit Agreement dated as of July 22, 2014 among Energy & Exploration Partners, Inc., a Delaware corporation, Energy & Exploration Partners, LLC, a Delaware limited liability company, the Lenders party thereto and CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH, as Administrative Agent and as Collateral Agent.

 

1  Select if applicable

 

A-1


6.       

AssignedInterest:

  

 

Aggregate Amount of

Loans for all Lenders

   Amount of
Loans
Assigned
     Percentage
Assigned
of Loans2
     CUSIP
Number

$                

   $                      %      

$                

   $                      %      

$                

   $                      %      

[Remainder of page intentionally left blank]

 

2  Set forth, to at least 9 decimals, as a percentage of the Commitment/Loans of all Lenders thereunder.

 

A-2


Effective Date:     , 20     [TO BE INSERTED BY ADMINISTRATIVE AGENT AND WHICH SHALL BE THE EFFECTIVE DATE OF RECORDATION OF TRANSFER IN THE REGISTER THEREFOR.]

The terms set forth in this Assignment are hereby agreed to:

 

ASSIGNOR

[NAME OF ASSIGNOR]

By:

   
  Name:
  Title:

ASSIGNEE

[NAME OF ASSIGNOR]

By:

 

 

  Name:
  Title:

 

A-3


[Consented to and]3 Accepted:

 

CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH

as Administrative Agent

By:

   
  Name:
  Title:
By:  

 

  Name:
  Title:

[Consented to:4

 

ENERGY & EXPLORATION PARTNERS, LLC

as Borrower

By:

   
Name:  

 

Title:  

                                                             ]

 

3  To be added only if the consent of the Administrative Agent is required by the terms of the Credit Agreement.
4  To be added only if the consent of the Borrower is required by the terms of the Credit Agreement.

 

A-4


ANNEX 1

STANDARD TERMS AND CONDITIONS FOR ASSIGNMENT

AND ACCEPTANCE

1. Representations and Warranties.

1.1 Assignor. The Assignor (a) represents and warrants that (i) it is the legal and beneficial owner of the Assigned Interest, (ii) the Assigned Interest is free and clear of any lien, encumbrance or other adverse claim and (iii) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and to consummate the transactions contemplated hereby; and (b) assumes no responsibility with respect to (i) any statements, warranties or representations made in or in connection with any Loan Document, (ii) the execution, legality, validity, enforceability, genuineness, sufficiency or value of the Credit Agreement or any other instrument or document delivered pursuant thereto, other than this Assignment (herein collectively the “Loan Documents”), or any collateral thereunder, (iii) the financial condition of Borrower (as defined in the Credit Agreement), any of its Subsidiaries or any of its or their respective obligations in respect of any Loan Document or (iv) the performance or observance by Borrower, any of its Subsidiaries or Affiliates or any other Person of any of their respective obligations under any Loan Document.

1.2 Assignee. The Assignee (a) represents and warrants that (i) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and to consummate the transactions contemplated hereby and to become a Lender under the Credit Agreement, (ii) it meets all requirements of an Eligible Assignee under the Credit Agreement and it satisfies all the other requirements, if any, specified in the Credit Agreement that are required to be satisfied by it in order to acquire the Assigned Interest and become a Lender, (iii) from and after the Effective Date, it shall be bound by the provisions of the Credit Agreement and, to the extent of the Assigned Interest, shall have the obligations of a Lender thereunder, (iv) it has received a copy of the Credit Agreement, together with copies of the most recent financial statements delivered pursuant to Section 5.05 thereof, as applicable, and such other documents and information as it has deemed appropriate to make its own credit analysis and decision to enter into this Assignment and to purchase the Assigned Interest on the basis of which it has made such analysis and decision and (v) if it is a Foreign Lender, attached to the Assignment is any documentation required to be delivered by it pursuant to the terms of the Credit Agreement, duly completed and executed by the Assignee; and (b) it agrees that (i) it will, independently and without reliance on Administrative Agent, the Assignor or any other Lender, and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under the Loan Documents, (ii) it appoints and authorizes the Administrative Agent and the Collateral Agent, respectively, by the terms hereof, together with such powers as are reasonably incidental thereto and (iii) it will perform in accordance with their terms all of the obligations which by the terms of the Loan Documents are required to be performed by it as a Lender.

 

A-5


2. Payments. From and after the Effective Date, Administrative Agent shall make all payments in respect of the Assigned Interest (including payments of principal, interest, fees and other amounts) to the Assignor for amounts which have accrued to but excluding the Effective Date and to the Assignee for amounts which have accrued from and after the Effective Date.

3. General Provisions. This Assignment shall be binding upon, and inure to the benefit of, the parties hereto and their respective successors and assigns. This Assignment may be executed in any number of counterparts, which together shall constitute one instrument. Delivery of an executed counterpart of a signature page of this Assignment by telecopy shall be effective as delivery of a manually executed counterpart of this Assignment. THIS AGREEMENT AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER SHALL BE CONSTRUED IN ACCORDANCE WITH AND GOVERNED BY THE LAWS OF THE STATE OF NEW YORK.

 

A-6


Exhibit A-2

to the Credit Agreement

FORM OF BORROWER PURCHASE ASSIGNMENT AND ACCEPTANCE

This Borrower Purchase Assignment and Acceptance (this “Assignment and Acceptance”) is dated as of the Effective Date set forth below and is entered into by and between the Assignor (as defined below) and the Assignee (as defined below). Capitalized terms used in this Assignment and Acceptance and not otherwise defined herein have the meanings specified in the Credit Agreement dated as of July 22, 2014 (as amended, supplemented or otherwise modified from time to time, the “Credit Agreement”), among the Borrower, Holdings, the Lenders from time to time party thereto (the “Lenders”), and CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH as administrative agent for the Lenders (in such capacity, including any successor thereto, the “Administrative Agent”) and as collateral agent for the Secured Parties. The Standard Terms and Conditions set forth in Annex 1 attached hereto are hereby agreed to and incorporated herein by reference and made a part of this Assignment and Acceptance as if set forth herein in full.

For an agreed consideration, the Assignor hereby irrevocably sells and assigns to the Assignee, and the Assignee hereby irrevocably purchases and assumes from the Assignor, subject to and in accordance with the Standard Terms and Conditions and the Credit Agreement, as of the Effective Date inserted by the Administrative Agent as contemplated below, (i) all of the Assignor’s rights and obligations in its capacity as a Lender under the Credit Agreement and any other documents or instruments delivered pursuant thereto to the extent related to the amount and percentage interest identified below of all of such outstanding rights and obligations of the Assignor under the facility identified below and (ii) to the extent permitted to be assigned under applicable law, all claims, suits, causes of action and any other right of the Assignor (in its capacity as a Lender) against any Person, whether known or unknown, arising under or in connection with the Credit Agreement, any other documents or instruments delivered pursuant thereto or the loan transactions governed thereby or in any way based on or related to any of the foregoing, including, but not limited to, contract claims, tort claims, malpractice claims, statutory claims and all other claims at law or in equity related to the rights and obligations sold and assigned pursuant to clause (i) above (the rights and obligations sold and assigned pursuant to clauses (i) and (ii) above being referred to herein collectively as the “Assigned Interest”). Such sale and assignment is without recourse to the Assignor and, except as expressly provided in this Assignment and Acceptance, without representation or warranty by the Assignor.

 

  1. Assignor (the “Assignor”):

 

  2. Assignee (the “Assignee”): [Energy & Exploration Partners, Inc.] [Energy & Exploration Partners, LLC]

 

  3. Borrower: Energy & Exploration Partners, LLC

 

  4. Administrative Agent: Credit Suisse AG, Cayman Islands Branch

 

A-1


  5. Assigned Interest:

 

Facility

   Aggregate Amount of
Commitment/Loans of
all Lenders
     Amount of
Commitment/Loans
Assigned
     Percentage
Assigned of
Commitment/
Loans5
 

Term Loans

   $                    $                                  

Effective Date:

 

5  Set forth, to at least 9 decimals, as a percentage of the Commitment/Loans of all Lenders thereunder.

 

A-2


The terms set forth in this Assignment and Acceptance are hereby agreed to:

 

[NAME OF ASSIGNOR], AS ASSIGNOR,

By:

   
  Name:
  Title:

 

[ENERGY & EXPLORATION PARTNERS, LLC] [ENERGY & EXPLORATION PARTNERS, INC.] AS ASSIGNEE,

By:

   
  Name:
  Title:

 

A-3


CONSENTED TO AND ACCEPTED:
CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH AS ADMINISTRATIVE AGENT,

By:

   
 

Name:

 

Title:

By:

 

 

 

Name:

 

Title:

 

A-4


ANNEX 1

STANDARD TERMS AND CONDITIONS FOR BORROWER PURCHASE

ASSIGNMENT AND ACCEPTANCE

1. Representations and Warranties.

1.1 Assignor. The Assignor (a) represents and warrants that (i) it is the legal and beneficial owner of the Assigned Interest, (ii) the Assigned Interest is free and clear of any lien, encumbrance or other adverse claim and (iii) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and to consummate the transactions contemplated hereby; and (b) assumes no responsibility with respect to (i) any statements, warranties or representations made in or in connection with any Loan Document, (ii) the execution, legality, validity, enforceability, genuineness, sufficiency or value of the Credit Agreement or any other instrument or document delivered pursuant thereto, other than this Assignment (herein collectively the “Loan Documents”), or any collateral thereunder, (iii) the financial condition of Borrower (as defined in the Credit Agreement), any of its Subsidiaries or any of its or their respective obligations in respect of any Loan Document or (iv) the performance or observance by Borrower, any of its Subsidiaries or Affiliates or any other Person of any of their respective obligations under any Loan Document.

1.2 Assignee. The Assignee (a) represents and warrants that (i) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and to consummate the transactions contemplated hereby, (ii) it meets all requirements of an Eligible Assignee under the Credit Agreement and it satisfies all the other requirements, if any, specified in the Credit Agreement that are required to be satisfied by it in order to acquire the Assigned Interest, (iii) no Event of Default has occurred and is continuing as of the time of effectiveness of this Assignment and Acceptance or would result therefrom and (iv) it does not have any material non-public information that either (x) has not been disclosed in writing to the Assignor (other than any such Assignor that does not wish to receive material non-public information) on or prior to the Effective Date or initiation of a Dutch auction by the Assignee or (y) if not disclosed to the Assignor, could reasonably be expected to have a material effect upon, or otherwise be material to, (1) the Assignor’s decision to make such assignment or (2) the market price of the Loans, in each case except to the extent that the Assignor has entered into a customary “big boy” letter with the Assignee, and (b) it agrees that, upon the Effective Date, the Loans purchased by Assignee hereunder shall be deemed canceled and no longer outstanding.

2. Payments. From and after the Effective Date, Administrative Agent shall make all payments in respect of the Assigned Interest (including payments of principal, interest, fees and other amounts) to the Assignor for amounts which have accrued to but excluding the Effective Date.

3. General Provisions. This Assignment shall be binding upon, and inure to the benefit of, the parties hereto and their respective successors and assigns. This

 

A-1


Assignment may be executed in any number of counterparts, which together shall constitute one instrument. Delivery of an executed counterpart of a signature page of this Assignment by telecopy shall be effective as delivery of a manually executed counterpart of this Assignment. THIS AGREEMENT AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER SHALL BE CONSTRUED IN ACCORDANCE WITH AND GOVERNED BY THE LAWS OF THE STATE OF NEW YORK.

 

A-2


Exhibit A-3

to the Credit Agreement

FORM OF AFFILIATED LENDER ASSIGNMENT AND ACCEPTANCE

This Affiliated Lender Assignment and Acceptance (this “Affiliated Lender Assignment and Acceptance”) is dated as of the Effective Date set forth below and is entered into by and between the Assignor (as defined below) and the Assignee (as defined below). Capitalized terms used in this Affiliated Lender Assignment and Acceptance and not otherwise defined herein shall have the meanings specified in the Credit Agreement dated as of [            ], 2014 (as amended, supplemented or otherwise modified from time to time, the “Credit Agreement”), among the Borrower, Holdings, the Lenders from time to time party thereto (the “Lenders”) and Credit Suisse AG, Cayman Islands Branch, as administrative agent for the Lenders (in such capacity, the “Administrative Agent”) and as collateral agent for the Secured Parties. The Standard Terms and Conditions set forth in Annex 1 attached hereto are hereby agreed to and incorporated herein by reference and made a part of this Affiliated Lender Assignment and Acceptance as if set forth herein in full.

For an agreed consideration, the Assignor hereby irrevocably sells and assigns to the Assignee, and the Assignee hereby irrevocably purchases and assumes from the Assignor, subject to and in accordance with the Standard Terms and Conditions and the Credit Agreement, as of the Effective Date inserted by the Administrative Agent as contemplated below, (i) all of the Assignor’s rights and obligations in its capacity as a Lender under the Credit Agreement and any other Loan Documents to the extent related to the amount and percentage interest identified below of all of such outstanding rights and obligations of the Assignor under the facility identified below and (ii) to the extent permitted to be assigned under applicable law, all claims, suits, causes of action and any other right of the Assignor (in its capacity as a Lender) against any Person, whether known or unknown, arising under or in connection with the Credit Agreement, any other Loan Documents or the Transactions or in any way based on or related to any of the foregoing, including, but not limited to, contract claims, tort claims, malpractice claims, statutory claims and all other claims at law or in equity related to the rights and obligations sold and assigned pursuant to clause (i) above (the rights and obligations sold and assigned pursuant to clauses (i) and (ii) above being referred to herein collectively as the “Assigned Interest”). Such sale and assignment is without recourse to the Assignor and, except as expressly provided in this Affiliated Lender Assignment and Acceptance, without representation or warranty by the Assignor.

 

  1. Assignor (the “Assignor”):

 

  2. Assignee (the “Assignee”):

 

  3. Borrower: Energy & Exploration Partners, LLC

 

  4. Administrative Agent: Credit Suisse AG, Cayman Islands Branch

 

  5. Assigned Interest:


Facility

   Aggregate Amount
of
Commitment/Loans
of all Lenders
     Amount of
Commitment/Loans
Assigned
     Percentage
Assigned of
Commitment/
Loans1
 

Loans

   $                    $                          

Effective Date of (the “Effective Date”)2:

 

1  Set forth, to at least 9 decimals, as a percentage of the Commitment/Loans of all Lenders thereunder.
2  To be inserted by the Administrative Agent and which shall be the effective date of recordation of the transfer in the register therefor.


The terms set forth in this Affiliated Lender Assignment and Acceptance are hereby agreed to:

 

[NAME OF ASSIGNOR], as Assignor
By:  

 

  Name:
  Title:
[NAME OF ASSIGNEE], as Assignee
By:  

 

  Name:
  Title:


Acknowledged:

 

CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH,

as Administrative Agent

By:  

 

  Name:
  Title:
By:  

 

  Name:
  Title:

Acknowledged:

 

ENERGY & EXPLORATION PARTNERS, LLC

By:  

 

  Name:
  Title:


ANNEX 1

STANDARD TERMS AND CONDITIONS FOR

AFFILIATED LENDER ASSIGNMENT AND ACCEPTANCE

1. Representations and Warranties.

1.1 Assignor. The Assignor (a) represents and warrants that (i) it is the legal and beneficial owner of the Assigned Interest, (ii) the Assigned Interest is free and clear of any lien, encumbrance or other adverse claim, (iii) its Commitments, and the outstanding balances of its Loans, in each case without giving effect to assignments thereof which have not become effective, are as set forth below and (iv) it has full power and authority, and has taken all action necessary, to execute and deliver this Affiliated Lender Assignment and Acceptance and to consummate the transactions contemplated hereby; and (b) assumes no responsibility with respect to (i) any statements, warranties or representations made in or in connection with the Credit Agreement or any other Loan Document, (ii) the execution, legality, validity, enforceability, genuineness, sufficiency or value of the Credit Agreement, any other Loan Document or any other instrument or document furnished pursuant thereto, (iii) the financial condition of the Borrower or any Subsidiary or any of their Affiliates or any other Person obligated in respect of the Credit Agreement or (iv) the performance or observance by the Borrower or any Subsidiary or any of their Affiliates or any other Person of any of their respective obligations under the Credit Agreement, any other Loan Document or any other instrument or document furnished pursuant thereto.

1.2. Assignee. The Assignee (a) represents and warrants that (i) it is an Affiliated Lender and has full power and authority, and has taken all action necessary, to execute and deliver this Affiliated Lender Assignment and Acceptance and to consummate the transactions contemplated hereby, (ii) it meets all requirements of an Eligible Assignee under the Credit Agreement and it satisfies all other the requirements, if any, specified in the Credit Agreement that are required to be satisfied by it in order to acquire the Assigned Interest and become a Lender, (iii) from and after the Effective Date, it shall be bound by the provisions of the Credit Agreement and, to the extent of the Assigned Interest, shall have the obligations of a Lender thereunder, (iv) it has received a copy of the Credit Agreement, together with copies of the most recent financial statements delivered pursuant to Section 5.05 thereof, as applicable, and such other documents and information as it has deemed appropriate to make its own credit analysis and decision to enter into this Affiliated Lender Assignment and Acceptance and to purchase the Assigned Interest on the basis of which it has made such analysis and decision, (v) if it is a Foreign Lender, attached to the Affiliated Lender Assignment and Acceptance is any documentation required to be delivered by it pursuant to the terms of the Credit Agreement, duly completed and executed by the Assignee, and (vi) it does not have any material non-public information that either (x) has not been disclosed in writing to the Assignor (other than any such Assignor that does not wish to receive material non-public information) on or prior to the Effective Date or (y) if not disclosed to the Assignor, could reasonably be expected to have a material effect upon, or otherwise be material to, (1) the Assignor’s decision to make such assignment or (2) the market price of the Loans, in each case except to the extent that the Assignor has entered into a customary “big boy” letter with the Assignee; and (b) agrees that (i) it will, independently and without reliance


on the Administrative Agent, the Assignor or any other Lender, and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under the Credit Agreement, (ii) it appoints and authorizes the Administrative Agent and the Collateral Agent to take such actions on its behalf and to exercise such powers under the Credit Agreement and the other Loan Documents as are delegated to them and (iii) it will perform in accordance with their terms all of the obligations which by the terms of the Credit Agreement and the other Loan Documents are required to be performed by it as a Lender or a Secured Party.

2. Other Agreements of the Assignee. The Assignee, solely in its capacity as a Lender, hereby agrees that if any Loan Party shall be subject to any bankruptcy proceeding, (A) the Assignee (in its capacity as such) shall not take any step or action in such bankruptcy proceeding to object to, impede, or delay the exercise of any right or the taking of any action by the Administrative Agent (or the taking of any action by a third party that is supported by the Administrative Agent) in relation to such Assignee’s claim with respect to its Loans (a “Claim”) (including objecting to any debtor in possession financing, use of cash collateral, grant of adequate protection, sale or disposition, compromise, or plan of reorganization) so long as such Assignee is treated in connection with such exercise or action on the same or better terms as the other Lenders and (B) with respect to any matter requiring the vote of Lenders during the pendency of a bankruptcy proceeding (including voting on any plan of reorganization), the Loans held by such Assignee (and any Claim with respect thereto) shall be deemed to be voted in accordance with Section 9.04(l)(iii) of the Credit Agreement, so long as such Assignee is treated in connection with the exercise of such right or taking of such action on the same or better terms as the other Lenders. For the avoidance of doubt, the Assignee agrees and acknowledges that the provisions set forth in this paragraph 2 constitute a “subordination agreement” as such term is contemplated by, and utilized in, Section 510(a) of the United States Bankruptcy Code, and, as such, would be enforceable for all purposes in any case where a Loan Party has filed for protection under any Debtor Relief Law applicable to such Loan Party.

3. Payments. From and after the Effective Date, the Administrative Agent shall make all payments in respect of the Assigned Interest (including payments of principal, interest, fees and other amounts) to the Assignor for amounts which have accrued to but excluding the Effective Date and to the Assignee for amounts which have accrued from and after the Effective Date.

4. General Provisions. This Affiliated Lender Assignment and Acceptance shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns. This Affiliated Lender Assignment and Acceptance may be executed in any number of counterparts, which together shall constitute one instrument. Delivery of an executed counterpart of a signature page of this Affiliated Lender Assignment and Acceptance by telecopy shall be effective as delivery of a manually executed counterpart of this Affiliated Lender Assignment and Acceptance. THIS AFFILIATED LENDER ASSIGNMENT AND ACCEPTANCE AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH THE LAW OF THE STATE OF NEW YORK.


Exhibit B

to the Credit Agreement

FORM OF BORROWING REQUEST

Credit Suisse AG, Cayman Islands Branch as

    Administrative Agent for the Lenders referred to

    below,

Eleven Madison Avenue,

New York, NY 10010

Attention of [            ]

[Date]

Ladies and Gentlemen:

The undersigned, ENERGY & EXPLORATION PARTNERS, LLC a Delaware limited liability company (the “Borrower”), refers to that certain Credit Agreement, dated as of July 22, 2014 (as may be amended, restated, replaced, refinanced, supplemented or otherwise modified from time to time, the “Credit Agreement”), among the Borrower, Holdings, the Lenders from time to time party thereto (the “Lenders”), and CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH as administrative agent for the Lenders (in such capacity, including any successor thereto, the “Administrative Agent) and as collateral agent for the Secured Parties. Capitalized terms used herein and not otherwise defined herein shall have the meanings assigned to such terms in the Credit Agreement. The Borrower hereby gives you notice pursuant to Section 2.03 of the Credit Agreement that it requests a Borrowing under the Credit Agreement, and in connection therewith sets forth below the terms on which such Borrowing is requested to be made:

 

(A)            
   [1.    Loans:      
      ¨    ABR:    US$[        ,        ,        ]
      ¨    Eurodollar, with an initial Interest Period of                      month(s):   
            US$[        ,        ,        ]]

 

(B)

  

Date of Borrowing

(which is a Business Day)

  

 

  

(C)

   Principal Amount of Borrowing   

 

  

 

B-1


(D)

  

Funds are requested to be disbursed to the Borrower’s account with                                 

(Account No.                              ).

(E)

   Type of Borrowing (Initial Loan or Incremental Loan, and, if Incremental Loan, whether Loans are to be Other Term Loans)

[Remainder of page intentionally left blank]

 

B-2


ENERGY & EXPLORATION PARTNERS, LLC,
By:  

 

  Name:
  Title:

 

B-3


Exhibit D

to the Credit Agreement

FORM OF COMPLIANCE CERTIFICATE

Reference is made to that certain Credit Agreement, dated as of July 22, 2014 (as amended, restated, replaced, supplemented or otherwise modified from time to time, the “Credit Agreement”), among Energy & Exploration Partners, LLC, a Delaware limited liability company (the “Borrower”), Energy & Exploration Partners, Inc., a Delaware corporation (“Holdings”), the other banks, other financial institutions and entities party thereto (the “Lenders”) and Credit Suisse AG, Cayman Islands Branch, as administrative agent for the Lenders (in such capacity, including any successor thereto, the “Administrative Agent”) and as collateral agent for the Secured Parties.

Terms defined in the Credit Agreement and not otherwise defined in this Compliance Certificate (this “Compliance Certificate”) shall have the meanings defined for them in the Credit Agreement. In the event of any conflict between the calculations set forth in this Compliance Certificate and the manner of calculation required by the Credit Agreement, the terms of the Credit Agreement shall govern and control.

The undersigned is the [Chief Financial Officer][Principal Accounting Officer] [Treasurer][Controller] of the Borrower, and certifies on behalf of the Borrower, and not in his or her individual capacity, as follows:

This Compliance Certificate is delivered in accordance with Section 5.05(c) of the Credit Agreement. This Compliance Certificate is delivered for the four consecutive fiscal quarters ended [            ], 20[    ]. Computations indicating compliance with respect to the covenant contained in Section 6.12 of the Credit Agreement are set forth on Annex A to this Compliance Certificate.

As of the date of this Compliance Certificate, no Default or Event of Default exists [, except as set forth in Annex B to this Compliance Certificate, specifying the nature and extent thereof and the corrective action taken or proposed to be taken with respect thereto].

[This Space Intentionally Left Blank]

 

D-1


The foregoing certifications, together with the computations set forth in Annex A hereto and the financial statements delivered with this Compliance Certificate in support hereof, are made and delivered as of [            ], 20[    ] pursuant to Section 5.05(c) of the Credit Agreement.

 

ENERGY & EXPLORATION PARTNERS, LLC,

a Delaware limited liability company

By:  

 

  Name:  
  Title:   [Chief Financial Officer][Principal Accounting Officer][Treasurer][Controller]

 

D-2


Annex A

to Compliance Certificate

FOR THE FOUR CONSECUTIVE FISCAL QUARTERS ENDING [            ], 20[    ].

Section 6.12 – Maximum Leverage Ratio. For the four consecutive fiscal quarters ending as of the date set forth above, the Leverage Ratio of the Borrower and the Consolidated Subsidiaries is             :1.00.8

The Leverage Ratio was computed as follows:

 

1. Total Funded Debt:

  

      $ [    ,    ,    ]   

to

              

1. Consolidated EBITDAX9: (i) + (ii) – (iii)

  

      $ [    ,    ,    ]   
     (i) Consolidated Net Income:       $ [    ,    ,    ]      
     (ii)       (a) interest:    $ [    ,    ,    ]         
      (b) income taxes:    $ [    ,    ,    ]         
      (c) depreciation:    $ [    ,    ,    ]         
      (d) depletion:    $ [    ,    ,    ]         
      (e) amortization (including non-cash amortization of deferred financing costs):    $ [    ,    ,    ]         
      (f) exploration expenses:    $ [    ,    ,    ]         
      (g) accretion of asset retirement obligations:    $ [    ,    ,    ]         
      (h) other similar noncash charges (including non-cash expenses relating to stock-based compensation and hedging, but excluding any non-cash charge to the extent it represents an accrual of or reserve for cash expenditures in any future period):    $ [    ,    ,    ]         

 

8  Commencing with the fiscal quarter ending December 31, 2014.
9  In the event of the consummation of any acquisition or Disposition during such applicable period, to be calculated after giving effect to any Pro Forma Adjustments. Consolidated EBITDAX (x) for the four consecutive fiscal quarters ending on September 30, 2014, shall equal Consolidated EBITDAX during the period from July 1, 2014 through September 30, 2014 multiplied by four (4), (y) for the four consecutive fiscal quarters ending on December 31, 2014, shall equal Consolidated EBITDAX during the period from July 1, 2014 through December 31, 2014 multiplied by two (2), and (z) for the four consecutive fiscal quarters ending on March 31, 2015, shall equal Consolidated EBITDAX during the period from July 1, 2014 through March 31, 2015 multiplied by 4/3.

 

D-3


      (i) reasonable expenses and charges related to any Investment, acquisition, Disposition, offering of Equity Interests, recapitalization, or issuance or incurrence of Indebtedness not prohibited by the Credit Agreement (in each case, whether or not successful)      $[    ,    ,    ]         
      (j) Transaction Costs      $[    ,    ,    ]         
      TOTAL of (ii)10:         $[    ,    ,    ]      
     (iii)       All non-cash income (excluding any non-cash income to the extent it represents the reversal of an accrual of or reserve for a potential cash item in any prior period) included in the calculation of Consolidated Net Income:         $[    ,    ,    ]      

The maximum Leverage Ratio is:

  

     [    ]:1.00   

In compliance

  

     [YES][NO]   

 

 

10  In the case of each item listed above, to the extent deducted from Consolidated Net Income in such period.

 

D-4


Exhibit G-1

to the Credit Agreement

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Lenders That Are Not Partnerships For U.S. Federal Income Tax Purposes)

Reference is made to that certain Credit Agreement, dated as of July 22, 2014 (as amended, restated, replaced, supplemented or otherwise modified from time to time, the “Credit Agreement”), among Energy & Exploration Partners, LLC, a Delaware limited liability company (the “Borrower”), Energy & Exploration Partners, Inc., a Delaware corporation (“Holdings”), the other banks, other financial institutions and entities party thereto (the “Lenders”) and Credit Suisse AG, Cayman Islands Branch, as administrative agent for the Lenders (in such capacity, including any successor thereto, the “Administrative Agent”) and as collateral agent for the Secured Parties.

Pursuant to the provisions of Section 2.20(e) of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record and beneficial owner of the Loan(s) (as well as any note(s) evidencing such Loan(s)) in respect of which it is providing this certificate, (ii) it is not a bank within the meaning of Section 881(c)(3)(A) of the Code, (iii) it is not a ten percent shareholder of the Borrower within the meaning of Section 881(c)(3)(B) of the Code and (iv) it is not a controlled foreign corporation related to the Borrower as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished the Administrative Agent and the Borrower with a certificate of its non-U.S. Person status on IRS Form W-8BEN. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform the Borrower and the Administrative Agent, and (2) the undersigned shall have at all times furnished the Borrower and the Administrative Agent with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

 

[NAME OF LENDER]
By:  

 

  Name:
  Title:

Date:                      , 20[     ]

 

G-1-1


Exhibit G-2

to the Credit Agreement

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Participants That Are Not Partnerships For U.S. Federal Income Tax Purposes)

Reference is made to that certain Credit Agreement, dated as of July 22, 2014 (as amended, restated, replaced, supplemented or otherwise modified from time to time, the “Credit Agreement”), among Energy & Exploration Partners, LLC, a Delaware limited liability company (the “Borrower”), Energy & Exploration Partners, Inc., a Delaware corporation (“Holdings”), the other banks, other financial institutions and entities party thereto (the “Lenders”) and Credit Suisse AG, Cayman Islands Branch, as administrative agent for the Lenders (in such capacity, including any successor thereto, the “Administrative Agent”) and as collateral agent for the Secured Parties.

Pursuant to the provisions of Section 2.20(e) of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record and beneficial owner of the participation in respect of which it is providing this certificate, (ii) it is not a bank within the meaning of Section 881(c)(3)(A) of the Code, (iii) it is not a ten percent shareholder of the Borrower within the meaning of Section 881(c)(3)(B) of the Code, and (iv) it is not a controlled foreign corporation related to the Borrower as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished its participating Lender with a certificate of its non-U.S. Person status on IRS Form W-8BEN. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform such Lender in writing, and (2) the undersigned shall have at all times furnished such Lender with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

 

[NAME OF PARTICIPANT]
By:  

 

  Name:
  Title:

Date:                      , 20[    ]

 

G-2-1


Exhibit G-3

to the Credit Agreement

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Participants That Are Partnerships For U.S. Federal Income Tax Purposes)

Reference is made to that certain Credit Agreement, dated as of July 22, 2014 (as amended, restated, replaced, supplemented or otherwise modified from time to time, the “Credit Agreement”), among Energy & Exploration Partners, Inc., a Delaware limited liability company (the “Borrower”), Energy & Exploration Partners, Inc., a Delaware corporation (“Holdings”), the other banks, other financial institutions and entities party thereto (the “Lenders”) and Credit Suisse AG, Cayman Islands Branch, as administrative agent for the Lenders (in such capacity, including any successor thereto, the “Administrative Agent”) and as collateral agent for the Secured Parties.

Pursuant to the provisions of Section 2.20(e) of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record owner of the participation in respect of which it is providing this certificate, (ii) its direct or indirect partners/members are the sole beneficial owners of such participation, (iii) with respect such participation, neither the undersigned nor any of its direct or indirect partners/members is a bank extending credit pursuant to a loan agreement entered into in the ordinary course of its trade or business within the meaning of Section 881(c)(3)(A) of the Code, (iv) none of its direct or indirect partners/members is a ten percent shareholder of the Borrower within the meaning of Section 881(c)(3)(B) of the Code and (v) none of its direct or indirect partners/members is a controlled foreign corporation related to the Borrower as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished its participating Lender with IRS Form W-8IMY accompanied by one of the following forms from each of its partners/members that is claiming the portfolio interest exemption: (i) an IRS Form W-8BEN or (ii) an IRS Form W-8IMY accompanied by an IRS Form W-8BEN from each of such partner’s/member’s beneficial owners that is claiming the portfolio interest exemption. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform such Lender and (2) the undersigned shall have at all times furnished such Lender with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

 

[NAME OF PARTICIPANT]
By:  

 

  Name:  
  Title:  

Date:                      , 20[    ]

 

G-3-1


Exhibit G-4

to the Credit Agreement

FORM OF U.S. TAX COMPLIANCE CERTIFICATE

(For Foreign Lenders That Are Partnerships For U.S. Federal Income Tax Purposes)

Reference is made to that certain Credit Agreement, dated as of July 22, 2014 (as amended, restated, replaced, supplemented or otherwise modified from time to time, the “Credit Agreement”), among Energy & Exploration Partners, LLC, a Delaware limited liability company (the “Borrower”), Energy & Exploration Partners, Inc., a Delaware corporation (“Holdings”), the other banks, other financial institutions and entities party thereto (the “Lenders”) and Credit Suisse AG, Cayman Islands Branch, as administrative agent for the Lenders (in such capacity, including any successor thereto, the “Administrative Agent”) and as collateral agent for the Secured Parties.

Pursuant to the provisions of Section 2.20(e) of the Credit Agreement, the undersigned hereby certifies that (i) it is the sole record owner of the Loan(s) (as well as any note(s) evidencing such Loan(s)) in respect of which it is providing this certificate, (ii) its direct or indirect partners/members are the sole beneficial owners of such Loan(s) (as well as any note(s) evidencing such Loan(s)), (iii) with respect to the extension of credit pursuant to this Credit Agreement or any other Loan Document, neither the undersigned nor any of its direct or indirect partners/members is a bank extending credit pursuant to a loan agreement entered into in the ordinary course of its trade or business within the meaning of Section 881(c)(3)(A) of the Code, (iv) none of its direct or indirect partners/members is a ten percent shareholder of the Borrower within the meaning of Section 881(c)(3)(B) of the Code and (v) none of its direct or indirect partners/members is a controlled foreign corporation related to the Borrower as described in Section 881(c)(3)(C) of the Code.

The undersigned has furnished the Administrative Agent and the Borrower with IRS Form W-8IMY accompanied by one of the following forms from each of its partners/members that is claiming the portfolio interest exemption: (i) an IRS Form W-8BEN or (ii) an IRS Form W-8IMY accompanied by an IRS Form W-8BEN from each of such partner’s/member’s beneficial owners that is claiming the portfolio interest exemption. By executing this certificate, the undersigned agrees that (1) if the information provided on this certificate changes, the undersigned shall promptly so inform the Borrower and the Administrative Agent, and (2) the undersigned shall have at all times furnished the Borrower and the Administrative Agent with a properly completed and currently effective certificate in either the calendar year in which each payment is to be made to the undersigned, or in either of the two calendar years preceding such payments.

 

G-4-1


Exhibit G-4

to the Credit Agreement

 

Unless otherwise defined herein, terms defined in the Credit Agreement and used herein shall have the meanings given to them in the Credit Agreement.

 

[NAME OF LENDER]
By:  

 

  Name:
  Title:

Date:                      , 20[    ]

 

G-4-2


Exhibit H

to the Credit Agreement

FORM OF MORTGAGE

MORTGAGE, DEED OF TRUST, ASSIGNMENT OF

PRODUCTION, SECURITY AGREEMENT AND FINANCING STATEMENT

FROM

ENERGY & EXPLORATION PARTNERS, LLC

TO

THE APPLICABLE TRUSTEE NAMED HEREIN

FOR THE BENEFIT OF

CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH, AS COLLATERAL AGENT

A CARBON, PHOTOGRAPHIC, OR OTHER REPRODUCTION OF THIS INSTRUMENT IS SUFFICIENT AS A FINANCING STATEMENT.

A POWER OF SALE HAS BEEN GRANTED IN THIS INSTRUMENT. IN CERTAIN STATES, A POWER OF SALE MAY ALLOW TRUSTEE OR MORTGAGEE TO TAKE THE MORTGAGED PROPERTY AND SELL IT WITHOUT GOING TO COURT IN A FORECLOSURE ACTION UPON DEFAULT BY MORTGAGOR UNDER THIS INSTRUMENT.

THIS INSTRUMENT CONTAINS AFTER-ACQUIRED PROPERTY PROVISIONS.

THIS INSTRUMENT SECURES PAYMENT OF FUTURE ADVANCES.

THIS INSTRUMENT COVERS PROCEEDS OF MORTGAGED PROPERTY.

THIS INSTRUMENT COVERS MINERALS AND OTHER SUBSTANCES OF VALUE WHICH MAY BE EXTRACTED FROM THE EARTH (INCLUDING WITHOUT LIMITATION OIL AND GAS) AND WHICH WILL BE FINANCED AT THE WELLHEADS OF THE WELL OR WELLS LOCATED ON THE PROPERTIES DESCRIBED ON EXHIBIT A HERETO. THIS FINANCING STATEMENT IS TO BE FILED OR FILED FOR RECORD, AMONG OTHER PLACES, IN THE REAL ESTATE RECORDS OR SIMILAR RECORDS OF THE COUNTY RECORDERS OF THE COUNTIES LISTED ON EXHIBIT A HERETO. THE GRANTOR HAS AN INTEREST OF RECORD IN THE REAL ESTATE CONCERNED, WHICH INTEREST IS DESCRIBED ON EXHIBIT A HERETO.

PORTIONS OF THE MORTGAGED PROPERTY ARE GOODS WHICH ARE OR ARE TO BECOME AFFIXED TO OR FIXTURES ON THE LAND DESCRIBED IN OR REFERRED TO ON EXHIBIT A HERETO. THIS FINANCING STATEMENT IS TO BE FILED FOR RECORD OR RECORDED, AMONG OTHER PLACES, IN THE REAL ESTATE RECORDS OR SIMILAR RECORDS OF EACH COUNTY IN WHICH SAID LAND OR ANY PORTION THEREOF IS LOCATED. THE GRANTOR IS THE OWNER OF RECORD INTEREST IN THE REAL ESTATE CONCERNED. THIS INSTRUMENT IS ALSO TO BE INDEXED IN THE INDEX OF FINANCING STATEMENTS.

WHEN RECORDED RETURN TO:

Haynes and Boone, LLP

1221 McKinney Street, Ste. 2100

Houston, Texas 77010

Attn: Randy Browne


Exhibit H

to the Credit Agreement

 

MORTGAGE, DEED OF TRUST, ASSIGNMENT OF PRODUCTION,

SECURITY AGREEMENT AND FINANCING STATEMENT

This MORTGAGE, DEED OF TRUST, ASSIGNMENT OF PRODUCTION, SECURITY AGREEMENT AND FINANCING STATEMENT (this “Mortgage”) is entered into this 22nd day of July, 2014 (the “Effective Date”), by Energy & Exploration Partners, LLC, a Delaware limited liability company, whose address for notice is Attn: Tom McNutt, Two City Place, 100 Throckmorton, Suite 1700, Fort Worth, Texas 76102 (“Mortgagor”), to NUPUR KUMAR, whose address for notice is Credit Suisse, Eleven Madison Avenue, 23rd Floor, New York, NY 10010, Attn: Loan Operations – Boutique Management, as Trustee (“Trustee”) for the benefit of CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH, as Collateral Agent (as hereinafter defined) and on behalf of the Secured Parties (as defined in the Credit Agreement referenced below), whose address for notice is Credit Suisse, Eleven Madison Avenue, 23rd Floor, New York, NY 10010, Attn: Loan Operations – Boutique Management (together with its successors in such capacity, “Mortgagee”). The Secured Parties and Mortgagee are herein sometimes collectively referred to as the “Beneficiaries”.

RECITALS:

A. This Mortgage is executed in connection with, and pursuant to the terms of the Credit Agreement dated as of July 22, 2014 (as hereafter renewed, extended, amended, supplemented, restated or modified from time to time, the “Credit Agreement”) among Energy & Exploration Partners, Inc., Energy & Exploration Partners, LLC, as borrower (in such capacity, “Borrower”), the lenders party thereto from time to time (the “Lenders”) and Mortgagee, as administrative agent for the Lenders and collateral agent (in such capacity, the “Collateral Agent”).

B. Borrower and the other Loan Parties may from time to time enter into, or have previously entered into, one or more (i) Cash Management Agreements and (ii) Hedging Agreements that, in the case of (i) and (ii), constitute Obligations.

THEREFORE, in order to comply with the terms and conditions of the Credit Agreement and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, Mortgagor hereby agrees with Mortgagee and Trustee, for the ratable benefit of the Beneficiaries, as follows:

10.

Grant of Lien and Indebtedness Secured

A. Grant of Liens. To secure payment of the Indebtedness (as defined in Section 1.02) and the performance of the covenants and obligations herein contained, Mortgagor does by these presents hereby GRANT, BARGAIN, SELL, CONVEY, TRANSFER, ASSIGN AND SET OVER to Trustee, and grant to Trustee a POWER OF SALE (pursuant to this Mortgage and applicable law) with respect to, all rights, titles, interests and estates now owned or hereafter acquired by Mortgagor in and to the following described properties, rights and interests, less and except the Excluded Property (collectively called the “Mortgaged Property”):

i. the oil and gas leases and/or the oil, gas and mineral leases (herein sometimes called the “Leases”), operating rights, forced pooling orders and farmout agreements and other contractual or other rights relating to oil, gas and mineral rights, described on, or described in the instruments described on, Exhibit A that is attached hereto and made a part hereof for all purposes, or such Leases that are otherwise mentioned or referred to therein and specifically, but without limitation, Mortgagor’s undivided interests in the Leases as specified on Exhibit A attached hereto and made a part hereof;


ii. (i) the properties now or hereafter pooled or unitized with the Leases; (ii) all presently existing or future unitization, communitization and pooling agreements and declarations of pooled units and the units created thereby (including, without limitation, all units created under orders, regulations, rules or other official acts of any Federal, State or other governmental body or agency having jurisdiction) that may affect all or any portion of the Leases including, without limitation, those units that may be described or referred to in Exhibit A; (iii) all operating agreements, contracts and other agreements described or referred to in this instrument that relate to any of the Leases or interests in the Leases described or referred to herein or in Exhibit A or to the production, sale, purchase, exchange, processing, gathering, compression, treating, storage or transportation of the Hydrocarbons (hereinafter defined) from or attributable to such Leases or interests; and (iv) the Leases even though Mortgagor’s interests therein be incorrectly described or a description of a part or all of such Leases or Mortgagor’s interests therein be omitted; it being intended by Mortgagor and Mortgagee herein to cover and affect all interests that Mortgagor may now own or may hereafter acquire in and to the Leases and interests in this paragraph (b), notwithstanding that the interests as specified in on Exhibit A may be limited to particular lands, specified depths or particular types of property interests;

iii. all oil, gas, casinghead gas, condensate, distillate, liquid hydrocarbons, gaseous hydrocarbons and all products refined therefrom and all other minerals in and under and/or which may be produced and saved from or attributable to the Leases, the lands covered thereby, pooled or unitized therewith and/or Mortgagor’s interests therein (herein collectively called the “Hydrocarbons”), including all oil in tanks and all rents, issues, profits, as-extracted collateral, proceeds, products, revenues and other income from or attributable to the Leases, the lands covered thereby, pooled or unitized therewith and/or Mortgagor’s interests therein that are subject to the liens and security interests of this Mortgage;

iv. all tenements, hereditaments, appurtenances and properties in anywise appertaining, belonging, affixed or incidental to the Leases, properties, rights, titles, interests and estates described or referred to in paragraphs (a), (b) and (c) above, which are now owned or which may hereafter be acquired by Mortgagor, but subject to the limitations, if any, set forth in Exhibit A, including, without limitation, any and all property, real or personal, now owned or hereafter acquired and situated upon or within the geographical boundaries covered by the Leases, used, held for use, or useful in connection with the operating, working or development of any of such Leases or properties (excluding drilling rigs, automotive equipment or other personal property that may be on such premises for the purpose of drilling a well or for other similar temporary uses) and including any and all oil wells, gas wells, salt water disposal wells, injection wells or other wells including without limitation those described in Exhibit A hereto, buildings, structures, field separators, flow-lines, separators, water treatment equipment or facilities, dehydrators, field separators, compressors, liquid extraction plants, plant compressors, pumps, pumping units, field gathering systems, tanks and tank batteries, fixtures, valves, fittings, machinery and parts, engines, boilers, meters, apparatus, equipment, appliances, tools, implements, cables, wires, towers, casing, tubing and rods, surface leases, rights-of-way, easements and servitudes together with all additions, substitutions, replacements, accessions and attachments to any and all of the foregoing properties;

v. the easements, rights-of-way, servitudes, fee tracts, real property, and permits, licenses, orders, certificates, and related instruments (collectively herein referred to as the “Easements”) described in Exhibit A or described in any instrument or document described in Exhibit A and any strips and gores within or adjoining any real property included in or covered by the Easements, all rights of ingress and egress to and from such real property, all easements, servitudes, rights-of-way, surface leases, fee tracts and other surface rights affecting said Easements, and all rights appertaining to the use and enjoyment of

 

2


said Easements, rights, estates, titles, claims, and interests, including, without limitation, lateral support, drainage, mineral, water, oil and gas rights (the Easements and all of the property and other rights, privileges, interests, titles, estates, and claims appurtenant thereto are herein collectively called the “Gathering System Premises”);

vi. all gathering systems and/or pipeline systems, and all materials, equipment, and other property now or hereafter located on the Gathering System Premises or used or held for use, regardless of where the same are located, in connection with, or otherwise related to such gathering systems and/or pipeline systems and all equipment, including, but not limited to, all fittings, furnishings, appliances, apparatus, machinery, gas processing, treatment, storage, transportation, extraction fractionation, exchange and/or manufacturing facilities and units and other units, gas, liquid product and other storage tanks, liquid product truck loading terminals, and other gathering assets now or hereafter located on or in (or, whether or not located thereon or therein, used or held for use in connection with) the Premises or such gathering systems or pipeline systems (that portion of the Mortgaged Property described in this paragraph (f) is herein collectively called the “Gathering Systems”);

vii. all materials, goods, surface or subsurface machinery, equipment, and other property now or hereafter located on the Gathering System Premises, and all other surface or subsurface machinery and equipment, line pipe and pipe connections, fittings, flanges, welds or interconnects, valves, control equipment, cathodic or electrical protection units, by-passes, regulators, drips, meters and metering stations, compression equipment, pumphouses and pumping stations, treating equipment, dehydration equipment, separation equipment, processing equipment, telephone, telegraph and other communication systems, office equipment and furniture, files and records, computer equipment and software, storage sheds, vehicles, loading docks, loading racks, towers, process tanks, storage tanks and other storage facilities, and shipping facilities, gas and electric fixtures, radiators, heaters, engines and machinery, boilers, elevators and motors, motor vehicles, pipes, faucets and other air conditioning, plumbing, and heating fixtures, refrigerators and appurtenances which relate to Mortgagor’s use of the Gathering Systems (collectively, the “Gathering System Equipment”), and all building materials and supplies now or hereafter delivered to the Gathering System Premises and intended to be installed thereon; all other personal property of whatever kind and nature at present contained in or hereafter placed on the Gathering System Premises in which Mortgagor has a possessory or title interest; and all renewals or replacements thereof or articles in substitution thereof; and all proceeds and profits thereof, all of which shall be deemed to be a portion of the security for the Indebtedness (as hereafter defined). If the lien of this Mortgage on any fixtures or personal property is subject to a lease agreement, conditional sales agreement or chattel mortgage covering such property, then all the right, title and interest of Mortgagor in and to any and all deposits made thereon or therefor are hereby assigned to Mortgagee, together with the benefit of any payments now or hereafter made thereon. Mortgagor also transfers, sets over and assigns to Mortgagee, its successors and assigns, all leases and use agreements covering machinery, Equipment and other personal property of Mortgagor related to the Gathering System Premises or the conduct of its business thereon, under which Mortgagor is the lessee of, or entitled to use, such items;

viii. all inventory and all materials used or consumed in the processing of inventory, and all products thereof, now or hereafter located in or on, or stored in or on, transported through or otherwise related to the lands covered by the Leases and the Gathering System Premises (herein collectively, the “Premises”), including all inventory (as such term is used in the Applicable UCC) and such other property held by Mortgagor for sale or lease (or in the possession of other persons while on lease or consignment) or furnished or to be furnished under any service contract and all raw materials, work in process and materials and supplies used or consumed in Mortgagor’s business relating to the Premises, and returned or repossessed goods, together with any bill of lading, dock warrant, dock receipt, warehouse receipt or order for the delivery of such goods of Mortgagor related to the Leases and Gathering System, and any other document which in the regular course of business or financing is treated

 

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as adequately evidencing that the person in possession of it is entitled to receive, hold and dispose of the document and the goods that it covers (the Mortgaged Property described in this paragraph (h) are herein collectively referred to as the “Inventory”), and all proceeds thereof and all accounts, contract rights and general intangibles under which such proceeds may arise, and together with all liens and security interests securing payment of the proceeds of the Inventory, including, but not limited to, those liens and security interests provided for under statutes enacted in the jurisdictions in which the Mortgaged Property is located;

ix. all presently existing and hereafter created Hydrocarbon purchase agreements, Hydrocarbon sales agreements, supply agreements, raw material purchase agreements, product purchase agreements, product sales agreements, processing agreements, exchange agreements, gathering agreements, transportation agreements and other contracts and agreements which cover, affect, or otherwise relate to the transportation and/or processing of Hydrocarbons through or in the Premises or any other part of the Mortgaged Property, and all other contracts and agreements (including, without limitation, equipment leases, maintenance agreements, electrical supply contracts, hedge or swap agreements, cap, floor, collar, exchange, forward or other hedge or protection agreements or transactions relating to crude oil, natural gas or other hydrocarbons, or any option with respect to any such agreement or transaction, and other contracts and agreements) which cover, affect or otherwise relate to the Premises, or any part thereof, together with any and all amendments, modifications, renewals or extensions (now or hereafter existing) to any of the foregoing (the Mortgaged Property described in this paragraph (i) are herein collectively called the “Contracts”);

x. all accounts, including but not limited to, (i) all of Mortgagor’s rights to receive payment, whether or not earned by Mortgagor’s performance and however acquired or evidenced, which arise out of or in connection with (A) Mortgagor’s sale of Hydrocarbons, (B) Mortgagor’s sale, assignment, lease, hiring out or allowance of use of, consignment, licensing or other voluntary disposition, whether permanent or temporary, of Inventory or other goods or property related to the Premises and/or the conduct of Mortgagor’s business thereon (including, without limitation, all payments received in lieu of payment for Inventory regardless of whether such payments accrued, and/or the events that gave rise to such payments occurred, on or before or after the date hereof, including, without limitation, “take or pay” or “minimum bill” payments and similar payments, payments received in settlement of or pursuant to a judgment rendered with respect to take or pay or minimum bill or similar obligations or other obligations under a sales contract, and payments received in buyout or other settlement of a contract covered by this Mortgage), (C) rendering of services related to the Gathering Systems and/or Premises and/or the conduct of Mortgagor’s business thereon or (D) any loan, advance, purchase of notes or other extension of credit made by Mortgagor; (ii) any and all rights and interests Mortgagor may have in connection with any of the transactions described in the preceding clause (i) and relating to the Gathering Systems and/or the Premises, whether now existing or hereafter acquired, (A) to demand and receive payment or other performance from any guarantor, surety, accommodation party or other person indirectly or secondarily obligated to Mortgagor in respect of the Leases, Hydrocarbons, Gathering Systems and/or the Premises and/or the conduct of Mortgagor’s business thereon, (B) arising out of the enforcement of any of Mortgagor’s rights to payment or performance by means of judicial or administrative proceedings, including, without limitation, any rights to receive payment under or in connection with any settlement of such proceedings, any judgment or any administrative order or decision arising out of actions related to the Leases, Hydrocarbons, Gathering Systems and/or the Premises and/or the conduct of Mortgagor’s business thereon, (C) in and to the goods or other property related to the Premises and/or the conduct of Mortgagor’s business thereon that is the subject of any such transaction, including, without limitation, (a) in the case of goods, an unpaid seller’s or lessor’s rights of rescission, replevin or to stop such goods in transit, and all rights to such goods on return or repossession, and (b) in the case of other property, rights of an unpaid seller, assignor or licensor to rescind or cancel the applicable agreement and demand the return of such property or, if such property is intangible, of any writing or other tangible evidence of its

 

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existence and/or disposition, and (D) to proceed against any collateral security related to the Premises provided by any obligor and to realize any proceeds thereof; and (iii) all contracts and other agreements and writings, all accounts, chattel paper, documents, general intangibles and instruments, and all other items of property now or hereafter owned by Mortgagor or in that Mortgagor now has or hereafter acquires any rights or interests, whether tangible or intangible and related to the Premises that in any way constitute, embody or evidence any payment rights described in clause (i) of this paragraph (j) or any of Mortgagor’s other rights and interests described in clause (ii) of this paragraph (j) (the Mortgaged Property described in this paragraph (j) are herein collectively referred to as the “Accounts Receivable”);

xi. all contracts, agreements, leases, permits, orders, franchises, servitudes, certificates, privileges, rights, technology, licenses and general intangibles (including, without limitation, all trademarks, trade names, and symbols) that are now or hereafter used, or held for use, in connection with or otherwise related to the Premises, the Gathering Systems, the Gathering System Equipment and/or the other items described in paragraph (g), the Inventory, the Contracts, and/or the Accounts Receivable (the Premises, the Gathering Systems, the Gathering System Equipment and the other items described in paragraph (g), the Inventory, the Contracts, and the Accounts Receivable are hereinafter collectively referred to as the “Property”) or the conduct of Mortgagor’s business on the Leases and/or Gathering System Premises whether now or hereafter created, acquired, or entered into and all right, title and interest of Mortgagor thereunder, including, without limitation, rights, incomes, profits, revenues, royalties, accounts, contract rights and general intangibles under any and all of the foregoing;

xii. any and all data, books and records related to the Premises and Mortgagor’s operations thereon, including, but not limited to, accounting records, files, computer software, employee records, engineering drawings or plans, surveys, site assessments, environmental reports, customer lists, production records, laboratory and testing records, sales and administrative records, and any other material or information relating to the ownership, maintenance, or operation of the Property (the “Books and Records”);

xiii. all unearned premiums, accrued, accruing or to accrue under insurance policies now or hereafter obtained by Mortgagor for the Property or the conduct of Mortgagor’s business on the Premises and all judgments, awards of damages and settlements hereafter made as a result of or in lieu of any taking of the Premises or any part thereof or any interest therein under the power of eminent domain, or for any damage (whether caused by such taking or otherwise) to the Leases and/or Gathering System Premises or any part thereof or interest therein, including any award for change of grade of streets;

xiv. all proceeds of the conversion, voluntary or involuntary, of the Property or any part thereof into cash or liquidated claims, including, without limitation, proceeds of hazard and title insurance, subject to the terms and conditions of this Mortgage;

xv. all options, extensions, improvements, betterments, renewals, substitutions and replacements of, and all additions and appurtenances to, the Property or any part thereof, hereafter acquired by, or released to, Mortgagor, or constructed, assembled or placed by Mortgagor on the Premises, and all conversions of the security constituted thereby (Mortgagor hereby acknowledging and agreeing that immediately upon such acquisition, release, construction, assembling, placement or conversion, as the case may be, and in each such case, without any further mortgage, conveyance, assignment or other act by Mortgagor, the same shall become subject to the lien of this Mortgage as fully and completely, and with the same effect, as though now owned by Mortgagor and specifically described herein);

 

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xvi. any property that may from time to time hereafter by delivery or by writing of any kind be subjected to the lien or security interests hereof by Mortgagor or by anyone on Mortgagor’s behalf; and Mortgagee is hereby authorized to receive the same at any time as additional security hereunder;

xvii. all other rights, titles and interests of every nature whatsoever now owned or hereafter acquired by Mortgagor in and to the Leases, Easements, properties, rights, titles, interests and estates and every part and parcel thereof, including, without limitation, said Leases, properties, rights, titles, interests and estates as the same may be enlarged by the discharge of any payments out of production or by the removal of any charges or Permitted Encumbrances (as defined on Exhibit A and herein so called) to which any of said Leases, Easements, properties, rights, titles, interests or estates are subject, or otherwise; together with any and all renewals and extensions of any of said Leases, Easements, properties, rights, titles, interests or estates; and all contracts and agreements supplemental to or amendatory of or in substitution for the Leases, Easements, the contracts and agreements described or mentioned above and any and all additional interests of any kind hereafter acquired by Mortgagor in and to said Leases, Easements, properties, rights, titles, interests or estates; and

xviii. all accounts, contract rights, inventory, general intangibles, insurance contracts and insurance proceeds constituting a part of, relating to or arising out of those portions of the Mortgaged Property that are described in paragraphs (a) through (q) above and all proceeds and products of all such portions of the Mortgaged Property and payments in lieu of production (such as “take or pay” payments), whether such proceeds or payments are goods, money, documents, instruments, chattel paper, securities, accounts, general intangibles, fixtures, real property, or other assets.

Any fractions or percentages specified in the attached Exhibit A in referring to Mortgagor’s interests are solely for purposes of the warranties made by Mortgagor pursuant to Section 3.01 hereof and shall in no manner limit the quantum of interest affected by this Section 1.01 with respect to any Mortgaged Property or with respect to any unit or well identified on Exhibit A.

TO HAVE AND TO HOLD the Mortgaged Property unto the Trustee, and its successors or substitutes in this trust, and to its or their successors and assigns, in trust to secure the payment and performance of the Indebtedness, however, upon the terms, provisions and conditions herein set forth.

Notwithstanding any provision in this Section 1.01 or in this Mortgage to the contrary, in no event are the following included in the definition of “Mortgaged Property” or hereby encumbered by this Mortgage:

Any Building (as defined in the applicable Flood Insurance Regulation) or Manufactured (Mobile) Home (as defined in the applicable Flood Insurance Regulation). As used herein, “Flood Insurance Regulations” shall mean (i) the National Flood Insurance Act of 1968 as now or hereafter in effect or any successor statute thereto, (ii) the Flood Disaster Protection Act of 1973 as now or hereafter in effect or any successor statue thereto, (iii) the National Flood Insurance Reform Act of 1994 (amending 42 USC 4001, et seq.), as the same may be amended or recodified from time to time, and (iv) the Flood Insurance Reform Act of 2004 and any regulations promulgated thereunder; and

Any Excluded Property. As used herein, “Excluded Property” means (a) any Equipment (as such term is defined in the Applicable UCC) subject to a purchase money security interest or equipment or capital lease (“Encumbered Equipment”) if and to the extent that the creation of a security interest in the right, title or interest of the Mortgagor in the Encumbered Equipment would cause or result in a default under any contractual provision or other restriction; (b) any rights or interest in any contract, license, permit or franchise covering real or personal property of the Mortgagor if, under the terms of the contract, license, permit or franchise or applicable law, the grant of a security interest or other Lien therein is

 

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prohibited as a matter of law, or under the terms of the contract, license, permit or franchise and that prohibition has not been effectively waived or the consent of the other party(ies) to such contract, license, permit or franchise has not been obtained, but the foregoing exclusions in no way will be construed (i) to apply to the extent that any described prohibition is unenforceable under Section 9-406, 9-407, 9-408, or 9-409 of the Applicable UCC (as same may be limited by other applicable law) or other applicable law, or (ii) to limit, impair or otherwise affect the continuing security interests of the Beneficiaries in and Liens upon any rights or interests of the Mortgagor in or to (A) monies due or to become due under any described contract, license, permit or franchise (including any Accounts (as defined in the Applicable UCC)), or (B) any proceeds from the sale, license, lease, or other dispositions of any such contract or license; (c) [intentionally omitted]; (d) assets subject to certificates of title; (e) “intent to use” trademark applications; (f) Deposit Accounts (as defined in the Applicable UCC); and (g) assets as to which the Mortgagee and the Borrower reasonably agree that the cost of obtaining a security interest or perfection thereof is excessive in relation to the benefit to the Beneficiaries of the security afforded thereby.

B. Indebtedness Secured. This Mortgage is executed and delivered by Mortgagor to secure and enforce the following (the “Indebtedness”):

i. the Obligations (including all future advances to be made under the Credit Agreement);

ii. any reasonable sums advanced or expenses or costs incurred by Trustee or the Mortgagee (or any receiver appointed hereunder) that are made or incurred pursuant to, or permitted by, the terms hereof, plus interest thereon at the rate herein specified or otherwise agreed upon, from the date of the advances or the incurring of such expenses or costs until reimbursed; and

iii. any extensions, refinancings, modifications or renewals of all such indebtedness and obligations described in subparagraphs (a) and (b) above, whether or not Mortgagor executes any extension agreement or renewal instrument. For the avoidance of doubt, the “Indebtedness” shall not include any Excluded Guarantor Obligations.

C. Fixture Filing, Etc. Without in any manner limiting the generality of any of the other provisions of this Mortgage: (i) some portions of the goods described or to which reference is made herein are or are to become fixtures on the land described or to which reference is made herein or on attached Exhibit A; (ii) the security interests created hereby under applicable provisions of the Applicable UCC will attach to Hydrocarbons (minerals including oil and gas), or the accounts resulting from the sale thereof at the wellhead or minehead located on the land described or to which reference is made herein; (iii) this Mortgage is to be filed of record in the real estate records as a financing statement, and (iv) Mortgagor is the record owner of the real estate or interests in the real estate comprised of the Mortgaged Property.

D. Waiver. Mortgagor specifically waives presentment, protest, notice of dishonor, intention to accelerate and acceleration.

E. Defined Terms. Any capitalized term used in this Mortgage and not defined in this Mortgage shall have the meaning assigned to such term in the Credit Agreement.

 

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11.

Assignment of Production

A. Assignment.

i. As of the Effective Date, Mortgagor has absolutely and unconditionally assigned, transferred, and conveyed, and does hereby absolutely and unconditionally assign, transfer and convey unto Mortgagee, its successors and assigns, all of the Hydrocarbons and all products obtained or processed therefrom, and the revenues and proceeds now and hereafter attributable to the Hydrocarbons and said products and all payments in lieu of the Hydrocarbons such as “take or pay” payments or settlements. Subject to the provisions of paragraph (g) below, the Hydrocarbons and products are to be delivered into transportation facilities or equipment serving the Mortgaged Property, or to the purchaser thereof, to the credit of Mortgagee, free and clear of all taxes, charges, costs and expenses; except applicable production taxes and royalties and similar burdens payable from production made under applicable agreements not prohibited by the Credit Agreement, and all such revenues and proceeds shall be paid directly to Mortgagee, at the address designated for payment under the Credit Agreement, with no duty or obligation of any party paying the same to inquire into the rights of Mortgagee to receive the same, what application is made thereof, or as to any other matter.

ii. Subject to the provisions of paragraph (g) below, Mortgagor agrees to perform all such acts, and to execute all such further assignments, transfers and division orders, and other instruments as may reasonably be required or desired by Mortgagee or any party in order to have said proceeds and revenues so paid to Mortgagee.

iii. Mortgagor hereby appoints Trustee and Mortgagee as its true and lawful attorney-in-fact for Mortgagor, with full authority in the place and stead of Mortgagor and from time to time in the discretion of Trustee or Mortgagee, to pursue any and all rights of Mortgagor to liens on and security interests in the Hydrocarbons securing payment of proceeds of runs attributable to the Hydrocarbons. The power of attorney granted to Trustee and Mortgagee in this Section 2.01(c), being coupled with an interest, shall be irrevocable until Security Termination (hereinafter defined) has occurred and shall be exercisable only during the continuance of any Event of Default.

iv. Subject to the provisions of paragraph (g) below, Mortgagee is fully authorized (i) to receive and receipt for said revenues and proceeds, (ii) to endorse and cash any and all checks and drafts payable to the order of Mortgagor or Mortgagee for the account of Mortgagor received from or in connection with said revenues or proceeds and to hold the proceeds thereof in a bank account as additional collateral securing the Indebtedness, and (iii) to execute transfer and division orders in the name of Mortgagor, or otherwise, with warranties binding Mortgagor. All proceeds received by Mortgagee pursuant to this assignment shall be applied as provided in Section 4.14 of this Mortgage.

v. Mortgagee shall not be liable for any delay, neglect, or failure to effect collection of any proceeds or to take any other action in connection therewith or hereunder; but Mortgagee shall have the right, at its election, in the name of Mortgagor or otherwise, to prosecute and defend any and all actions or legal proceedings deemed advisable by Mortgagee in order to collect such funds and to protect the interests of Mortgagee, and/or Mortgagor, with all costs, expenses and attorneys’ fees incurred in connection therewith being paid by Mortgagor.

vi. In addition to the rights granted to Mortgagee in Section 1.01 of this Mortgage, Mortgagor hereby further collaterally transfers and assigns to Mortgagee any and all liens, security interests, financing statements or similar interests of Mortgagor attributable to its interest in the

 

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Hydrocarbons and proceeds of runs therefrom arising under or created by the provisions of §§ 9.319 and 9.343 of the Applicable UCC and of any similar state or local jurisdiction statute in any state wherein the Mortgaged Property is located or by any other statutory provision, judicial decision or otherwise (collectively, the “Assigned Liens and Security Interests”).

vii. Until such time as an Event of Default has occurred and is continuing, Mortgagee hereby grants to Mortgagor a license to all of the Hydrocarbons and to sell, collect, receive and receipt for all revenues and proceeds from the sale of Hydrocarbons and the products obtained or processed therefrom, as well as any Assigned Liens and Security Interests, and to retain, use and enjoy same.

viii. In the event Security Termination or of a release of this Mortgage as to the Mortgaged Property, or any part thereof, the assignment granted in this Section 2.01 shall terminate and be of no further force and effect with respect to all of the Mortgaged Property, in the case of Security Termination, or the Mortgaged Property so released.

B. No Modification of Payment Indebtedness. Nothing herein contained shall modify or otherwise alter the obligation of Mortgagor to make prompt payment of all principal and interest owing on the Indebtedness when and as the same become due regardless of whether the proceeds of the Hydrocarbons are sufficient to pay the same and the rights provided in accordance with the foregoing assignment provision shall be cumulative of all other security of any and every character now or hereafter existing to secure payment of the Indebtedness.

12.

Representations, Warranties and Covenants

Mortgagor hereby represents, warrants and covenants as follows:

A. Title; Mortgaged Property.

i. Except as could not reasonably be expected to have a Material Adverse Effect, Mortgagor has good and defensible title to, or valid leasehold interests in, the Mortgaged Property to the extent evaluated in the most recently delivered Reserve Report, subject to Liens permitted under Section 6.02 of the Credit Agreement. All such Mortgaged Property are free and clear of Liens, other than Liens expressly permitted by Section 6.02 of the Credit Agreement. The Mortgagor owns in all material respects the net interests in production attributable to its Mortgaged Property as reflected in the most recently delivered Reserve Report, and the ownership of such properties does not in any material respect obligate Mortgagor to bear the costs and expenses relating to the maintenance, development and operations of each such property in an amount in excess of the working interest of each property set forth in the most recently delivered Reserve Report that is not offset by a corresponding proportionate increase in its net revenue interest in such property or the revenues therefrom.

ii. The provisions in Sections 3.07, 3.14, 3.17, 5.02, 5.12 and 6.05 of the Credit Agreement shall apply to this Mortgage with respect to Mortgagor and the Mortgaged Property, and the provisions of Section 9.01 of the Credit Agreement with respect to notices relating to the Credit Agreement shall apply to notices and communications relating to this Mortgage, and all of such provisions are hereby incorporated into this Section 3.01 by reference, mutatis mutandis, as a part hereof.

iii. This Mortgage is, and shall always constitute, a perfected Lien on, and security interest in, all right, title and interest of the Mortgagor in the Mortgaged Property subject only to Permitted Encumbrances, and, other than the Permitted Encumbrances, Mortgagor will not create or suffer to be created or permit to exist any Lien other than Permitted Encumbrances prior or junior to or on a parity with the lien and security interest of this Mortgage upon the Mortgaged Property or any part thereof or upon the rents, issues, revenues, profits and other income therefrom.

 

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B. Other General Representations, Warranties and Covenants.

i. Mortgagor shall maintain insurance on the Mortgaged Property as required by the Credit Agreement. Pursuant to this Mortgage Mortgagor is hereby granting to Mortgagee a security interest in all proceeds from such policies as additional security for the Indebtedness.

ii. Consistent with the terms of the Credit Agreement, Mortgagor shall cure promptly any defects in the execution and delivery of this instrument. Mortgagor at Mortgagor’s expense will promptly execute and deliver to Mortgagee upon reasonable request all such other and further documents, agreements and instruments in compliance with or accomplishment of the covenants and agreements of Mortgagor herein or to further evidence and more fully describe the Mortgaged Property, or to correct any omissions in this instrument, or more fully to state the security obligations set out herein, or to perfect, protect and, or, preserve any lien or security interest created hereby, or to make any recordings, or to file any notices, or obtain any consents, all as may be necessary or appropriate in connection with any thereof. Mortgagor shall pay for all reasonable costs of preparing, recording and releasing any of the above.

iii. Mortgagor is not a public utility and is not otherwise subject to regulation by any public utility commission or any similar federal, state or local agency or governmental body.

iv. Mortgagor is not a nonresident alien, foreign corporation, foreign partnership, foreign trust, foreign estate or foreign person within the meaning of Sections 1445 or 7701 of the Internal Revenue Code of 1986, as amended, or the regulations thereto.

v. Mortgagor has full power and lawful authority to grant, bargain, sell, assign, transfer, mortgage and convey a Lien upon all of the Mortgaged Property and Collateral in the manner and form herein provided.

C. Failure to Perform. Mortgagor agrees that if Mortgagor fails to perform any act or to take any action which Mortgagor is required to perform or take hereunder or pay any money which Mortgagor is required to pay hereunder, Mortgagee and Trustee, in Mortgagor’s name or its own, may, but shall not be obligated to, perform or cause to perform such act or take such action or pay such money, and any expenses so incurred by either of them and any money so paid by either of them shall be a demand obligation owing by Mortgagor to Mortgagee or Trustee, as the case may be, and each of Mortgagee and Trustee, upon making such payment, shall be subrogated to all of the rights of the Person receiving such payment. Each amount due and owing by Mortgagor to each of Mortgagee and Trustee pursuant to this Mortgage shall bear interest from the date of such expenditure or payment or other occurrence which gives rise to such amount being owed to such Person until paid at the Default Rate (hereinafter defined), and all such amounts together with such interest thereon shall be a part of the Indebtedness.

D. ENVIRONMENTAL INDEMNIFICATION. TO THE FULL EXTENT PERMITTED BY APPLICABLE LAW, MORTGAGOR AGREES TO DEFEND, INDEMNIFY AND HOLD HARMLESS MORTGAGEE, AND ITS RESPECTIVE TRUSTEES, DIRECTORS, OFFICERS, EMPLOYEES, ATTORNEYS AND THE SECURED PARTIES (“INDEMNIFIED PARTIES”) FROM AND AGAINST ANY AND ALL LOSS, COST, EXPENSE OR LIABILITY (INCLUDING REASONABLE ATTORNEYS’ FEES AND COURT COSTS) INCURRED BY ANY INDEMNIFIED PARTY IN CONNECTION WITH OR OTHERWISE ARISING OUT OF ANY AND ALL CLAIMS OR PROCEEDINGS (WHETHER BROUGHT BY A PRIVATE PARTY, GOVERNMENTAL

 

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AGENCY OR OTHERWISE) FOR ENVIRONMENTAL CLAIMS RELATED TO HAZARDOUS SUBSTANCES LOCATED UPON, MIGRATING INTO, FROM OR THROUGH OR OTHERWISE RELATING TO THE MORTGAGED PROPERTY (WHETHER OR NOT THE RELEASE OF SUCH HAZARDOUS SUBSTANCES WAS CAUSED BY MORTGAGOR, ANOTHER OWNER OR OPERATOR OF THE MORTGAGED PROPERTY, A PRIOR OWNER OR OPERATOR OR ANY OTHER PARTY AND WHETHER OR NOT THE ALLEGED LIABILITY IS ATTRIBUTABLE TO THE HANDLING, STORAGE, GENERATION, TRANSPORTATION OR DISPOSAL OF SUCH SUBSTANCES OR THE MERE PRESENCE OF THE SUBSTANCES ON THE MORTGAGED PROPERTY), THAT ANY INDEMNIFIED PARTY MAY INCUR BY REASON OF THIS MORTGAGE, THE MAKING OF THE LOANS OR THE EXERCISE OF ANY OF ITS RIGHTS UNDER THIS MORTGAGE, INCLUDING ANY LOSS, COST, EXPENSE OR LIABILITY DUE TO ANY INDEMNIFIED PARTIES’ NEGLIGENCE, BUT EXCLUDING ANY LOSS, CLAIM, DAMAGE, COST, EXPENSE OR LIABILITY DUE TO ANY INDEMNIFIED PARTY’S GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OR IN RESPECT OF ANY PROCEEDING NOT RESULTING FROM AN ACT OR OMISSION BY THE MORTGAGOR OR ITS AFFILIATES, OR THEIR PREDECESSORS IN INTEREST, THAT IS BROUGHT BY AN INDEMNIFIED PARTY AGAINST ANOTHER INDEMNIFIED PARTY. THE PROVISIONS OF THIS SECTION 3.04 SHALL SURVIVE, AND SHALL IN NO MANNER OR TO ANY EXTENT BE EXTINGUISHED, DIMINISHED, NOVATED OR AFFECTED BY, ANY FORECLOSURE OF THE LIENS CREATED BY THIS MORTGAGE OR ANY CONVEYANCE IN LIEU OF FORECLOSURE, THE OCCURRENCE OF SECURITY TERMINATION OR THE DISCHARGE AND RELEASE OF THIS MORTGAGE.

13.

Rights and Remedies

A. Event of Default. The term “Event of Default” as used in this Mortgage shall mean the occurrence of any “Events of Default” under the Credit Agreement.

B. Foreclosure and Sale. If an Event of Default shall occur and be continuing, Mortgagee shall have the right and option to proceed with foreclosure by directing Trustee, or his successors or substitutes in trust, to proceed with foreclosure and to sell, to the extent permitted by law, all or any portion of the Mortgaged Property at one or more sales, as an entirety or in parcels, at such place or places in otherwise such manner and upon such notice as may be required by law, or, in the absence of any such requirement, as Mortgagee may deem appropriate, and to make conveyance to the purchaser or purchasers. Where the Mortgaged Property is situated in more than one county in any state, notice as above provided shall be posted and filed in all such counties (if such notices are required by law), and all such Mortgaged Property may be sold in any such county and any such notice shall designate the county where such Mortgaged Property is to be sold. Nothing contained in this Section 4.02 shall be construed so as to limit in any way Trustee’s rights to sell the Mortgaged Property, or any portion thereof, by private sale if, and to the extent that, such private sale is permitted under the laws of the applicable jurisdiction or by public or private sale after entry of a judgment by any court of competent jurisdiction so ordering. Mortgagor hereby irrevocably appoints Trustee to be the attorney of Mortgagor with respect to the conduct of any such sale and in the name and on behalf of Mortgagor to execute and deliver any deeds, transfers, conveyances, assignments, assurances and notices with respect to such sale which Mortgagor ought to execute and deliver and do and perform any and all such acts and things with respect to such sale which Mortgagor ought to do and perform under the covenants herein contained. At any such sale: (i) whether made under the power herein contained or any other legal enactment, or by virtue of any judicial proceedings or any other legal right, remedy or recourse, it shall not be necessary for Trustee to have physically present, or to have constructive possession of, the Mortgaged Property (Mortgagor hereby covenanting and agreeing to deliver to Trustee any portion of the Mortgaged Property not actually or

 

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constructively possessed by Trustee immediately upon demand by Trustee) and the title to and right of possession of any such property shall pass to the purchaser thereof as completely as if the same had been actually present and delivered to purchaser at such sale, (ii) each instrument of conveyance executed by Trustee shall contain a general warranty of title, binding upon Mortgagor and its successors and assigns, (iii) each and every recital contained in any instrument of conveyance made by Trustee shall be prima facie evidence of the truth and accuracy of the matters recited therein, including, without limitation, nonpayment of the Indebtedness, advertisement and conduct of such sale in the manner provided herein and otherwise by law and appointment of any successor Trustee hereunder, (iv) any and all prerequisites to the validity thereof shall be presumed to have been performed, (v) the receipt of Trustee or of such other party or officer making the sale shall be a sufficient discharge to the purchaser or purchasers for its purchase money and no such purchaser or purchasers, or its assigns or personal representatives, shall thereafter be obligated to see to the application of such purchase money, or be in any way answerable for any loss, misapplication or nonapplication thereof, (vi) to the fullest extent permitted by law, Mortgagor shall be completely and irrevocably divested of all of its right, title, interest, claim and demand whatsoever, either at law or in equity, in and to the property sold, and such sale shall be a perpetual bar both at law and in equity against Mortgagor, and against any and all other persons claiming or to claim the property sold or any part thereof, by, through or under Mortgagor and (vii) to the extent and under such circumstances as are permitted by law, Mortgagee may be a purchaser at any such sale and shall have the right, after paying or accounting for all costs of said sale or sales, to credit the amount of the bid upon the amount of the Indebtedness (in the order of priority set forth in Section 4.14 hereof) in lieu of cash payment.

i. Texas. Any sale of any part of the Mortgaged Property located in the State of Texas shall be made in conformity to the laws thereof including: upon the occurrence and during the continuance of an Event of Default, Mortgagor hereby authorizes and empowers Trustee, and each and all of his successors in this trust, at the request of the Mortgagee, at any time when an Event of Default shall have occurred and be continuing to sell the Mortgaged Property at public vendue due to the highest bidder, for cash, between the hours of 10:00 a.m. and 4:00 p.m. of the first Tuesday of any month, after having given notice of the sale at least twenty-one (21) days prior to the date of the sale, in the manner hereinafter described, in the county in which the Mortgaged Property, or any part thereof is situated; provided that, if the Mortgaged Property is situated in more than one county, such sale of the Mortgaged Property, or part thereof, may be made in any county in the State of Texas wherein any part of the Mortgaged Property is situated. The sale shall be made at the area of the county courthouse designated for such sales by the Commissioner’s Court of such county in an instrument heretofore recorded in the real property records of that county; provided that, if said Commissioner’s Court has not heretofore recorded a written instrument designating the area in which such sales shall occur in the real property records of such county, then the sale shall take place at the area of the county courthouse designated in the notice of sale. The sale shall begin at the time stated in the notice of sale or not later than three (3) hours after that time. The notice of sale shall include a statement of the earliest time at which the sale will occur and shall be given by posting (or by having some person or persons acting for Trustee post), for at least twenty-one (21) days preceding the date of the sale, written or printed notice of the proposed sale at the courthouse door of said county in which the sale is to be made, and if such property is in more than one county, one such notice of sale shall be posted at the Courthouse door of each county in which part of such property is situated and such property may be sold at the courthouse door of any one of such counties, and the notice so posted shall designate in which county such property shall be sold; in addition to such posting of notice, Trustee shall, at least twenty-one (21) days preceding the date of sale, file a copy of such written notice of the proposed sale in the office of the county clerk of the county in which the sale is to be made, and if such property is in more than one county, a copy of such written notice of sale shall be so filed in the office of the county clerk of each county in which part of such property is situated; in addition to such posting and filing of notice, Mortgagee shall, at least twenty-one (21) days preceding the date of sale, serve written or printed notice of the proposed sale by certified mail on Mortgagor. Service of such notice shall be completed

 

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upon deposit of the notice, enclosed in a postpaid wrapper, properly addressed to Mortgagor at its most recent address or addresses as shown by the records of Mortgagee, in a post office or official depository under the care and custody of the United States Postal Service. The affidavit of any person having knowledge of the facts to the effect that such service was completed shall be prima facie evidence of the fact of service. Mortgagor agrees that no notice of any such sale other than as set out in this paragraph and in Section 3.01(b) need be given by Trustee, Mortgagee or any other person. Mortgagor hereby designates as its address for the purposes of such notice, the address set out hereinabove, and agrees that such address shall be changed only in accordance with the provisions of Section 9.01 of the Credit Agreement as incorporated herein by reference in Section 3.01(b). Upon the occurrence and during the continuance of an Event of Default, Mortgagor hereby authorizes and empowers Trustee, and each and all of Trustee’s successors in this trust, to sell the Mortgaged Property, or any interest or estate in the Mortgaged Property together or in lots or parcels, as such Trustee shall deem expedient, and to execute and deliver to the purchaser or purchasers of the Mortgaged Property good and sufficient deed or deeds of conveyance thereof and bills of sale with covenants of general warranty binding on Mortgagor and its successors and assigns.

ii. Federal and Indian Lands. Upon a sale conducted pursuant to this Article IV during any Event of Default of all or any portion of the Mortgaged Property consisting of interests (the “Federal Interests”) in leases, easements, rights-of-way, agreements or other documents and instruments covering, affecting or otherwise relating to federal or tribal lands (including, without limitation, leases, easements and rights-of-way issued by the Bureau of Land Management), Mortgagor agrees to take all action and execute all instruments necessary or advisable to transfer the Federal Interests to the purchaser at such sale, including, without limitation, to execute, acknowledge and deliver assignments of the Federal Interests on officially approved forms in sufficient counterparts to satisfy applicable statutory and regulatory requirements, to seek and request approval thereof and to take all other action necessary or advisable in connection therewith. Mortgagor hereby irrevocably appoints Trustee as Mortgagor’s attorney-in-fact and proxy, with full power and authority in the place and stead of Mortgagor, in the name of Mortgagor or otherwise, to take any such action and to execute any such instruments on behalf of Mortgagor that Trustee may deem necessary or advisable to so transfer the Federal Interests, including, without limitation, the power and authority to execute, acknowledge and deliver such assignments, to seek and request approval thereof and to take all other action deemed necessary or advisable by Trustee in connection therewith; and Mortgagor hereby adopts, ratifies and confirms all such actions and instruments. Such power of attorney and proxy is coupled with an interest, shall survive the dissolution, termination, reorganization or other incapacity of Mortgagor and shall be irrevocable. No such action by Trustee shall constitute acknowledgment of, or assumption of liabilities relating to, the Federal Interests, and neither Mortgagor nor any other party may claim that Trustee is bound, directly or indirectly, by any such action.

C. Substitute Trustees and Agents. Trustee or its successor or substitute may appoint or delegate any one or more persons as agent to perform any act or acts necessary or incident to any sale held by Trustee, including the posting of notices and the conduct of sale, but in the name and on behalf of Trustee, his successor or substitute. If Trustee or his successor or substitute shall have given notice of sale hereunder, any successor or substitute trustee thereafter appointed may complete the sale and the conveyance of the property pursuant thereto as if such notice had been given by the successor or substitute trustee conducting the sale.

D. Judicial Foreclosure; Receivership. At any time after the occurrence and during the continuance of an Event of Default, Trustee or Mortgagee shall have the right and power to proceed by a suit or suits in equity or at law, whether for the specific performance of any covenant or agreement herein contained or in aid of the execution of any power herein granted, or for any foreclosure hereunder or for the sale of the Mortgaged Property under the judgment or decree of any court or courts of competent

 

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jurisdiction, or for the appointment of a receiver pending any foreclosure hereunder or the sale of the Mortgaged Property under the order of a court or courts of competent jurisdiction or under executory or other legal process, or for the enforcement of any other appropriate legal or equitable remedy. Any money advanced by Trustee and/or Mortgagee in connection with any such receivership shall be a demand obligation (which obligation Mortgagor hereby expressly promises to pay) owing by Mortgagor to Trustee and/or Mortgagee and shall bear interest from the date of making such advance by Trustee and/or Mortgagee until paid at the Default Rate.

E. Foreclosure for Installments. If an Event of Default shall have occurred and be continuing, Mortgagee shall also have the option to proceed with foreclosure in satisfaction of any installments of the Indebtedness which have not been paid when due either through the courts or by directing Trustee or his successors in trust to proceed with foreclosure in satisfaction of the matured but unpaid portion of the Indebtedness as if under a full foreclosure, conducting the sale as herein provided and without declaring the entire principal balance and accrued interest due; such sale may be made subject to the unmatured portion of the Indebtedness, and any such sale shall not in any manner affect the unmatured portion of the Indebtedness, but as to such unmatured portion of the Indebtedness this Mortgage shall remain in full force and effect just as though no sale had been made hereunder. It is further agreed that several sales may be made hereunder without exhausting the right of sale for any unmatured part of the Indebtedness, it being the purpose hereof to provide for a foreclosure and sale of the security for any matured portion of the Indebtedness without exhausting the power to foreclose and sell the Mortgaged Property for any subsequently maturing portion of the Indebtedness.

F. Separate Sales. The Mortgaged Property may be sold in one or more parcels and in such manner and order as Mortgagee, in its sole discretion, may elect, it being expressly understood and agreed that the right of sale arising out of any Event of Default shall not be exhausted by any one or more sales.

G. Possession of Mortgaged Property. Mortgagor agrees to the full extent that it lawfully may, that, during the occurrence and continuance of an Event of Default, then, and in every such case, Trustee or Mortgagee shall have the right and power to enter into and upon and take possession of all or any part of the Mortgaged Property in the possession of Mortgagor, its successors or assigns, or its or their agents or servants, and may exclude Mortgagor, its successors or assigns, and all persons claiming under Mortgagor, and its or their agents or servants wholly or partly therefrom; and, holding the same, Trustee may use, administer, manage, operate and control the Mortgaged Property and conduct the business thereof to the same extent as Mortgagor, its successors or assigns, might at the time do and may exercise all rights and powers of Mortgagor, in the name, place and stead of Mortgagor, or otherwise as Trustee shall deem best. All costs, expenses and liabilities of every character incurred by Trustee and/or Mortgagee in administering, managing, operating, and controlling the Mortgaged Property shall constitute a demand obligation (which obligation Mortgagor hereby expressly promises to pay) owing by Mortgagor to Trustee and/or Mortgagee and shall bear interest from date of expenditure until paid at the Default Rate, all of which shall constitute a portion of the Indebtedness and shall be secured by this Mortgage and all other Security Documents.

H. Occupancy After Foreclosure. In the event there is a foreclosure sale hereunder and at the time of such sale Mortgagor or Mortgagor’s heirs, devisees, representatives, successors or assigns or any other person claiming any interest in the Mortgaged Property by, through or under Mortgagor, are occupying or using the Mortgaged Property or any part thereof, each and all shall immediately become the tenant of the purchaser at such sale, which tenancy shall be a tenancy from day to day, terminable at the will of either the landlord or tenant, at a reasonable rental per day based upon the value of the property occupied, such rental to be due daily to the purchaser; to the extent permitted by applicable law, the purchaser at such sale shall, notwithstanding any language herein apparently to the contrary, have the sole option to demand immediate possession following the sale or to permit the occupants to remain as tenants

 

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at will. In the event the tenant fails to surrender possession of said property upon demand, the purchaser shall be entitled to institute and maintain a summary action for possession of the Mortgaged Property (such as an action for forcible entry and detainer) in any court having jurisdiction.

I. Remedies Cumulative, Concurrent and Nonexclusive. Every right, power and remedy herein given to Trustee or Mortgagee shall be cumulative and in addition to every other right, power and remedy herein specifically given or now or hereafter existing in equity, at law or by statute (including specifically those granted by the Applicable UCC in effect and applicable to the Mortgaged Property or any portion thereof), and each and every such right, power and remedy whether specifically herein given or otherwise existing may be exercised from time to time and so often and in such order as may be deemed expedient by Trustee or Mortgagee, and the exercise, or the beginning of the exercise, of any such right, power or remedy shall not be deemed a waiver of the right to exercise, at the same time or thereafter any other right, power or remedy. No delay or omission by Trustee or Mortgagee in the exercise of any right, power or remedy shall impair any such right, power or remedy or operate as a waiver thereof or of any other right, power or remedy then or thereafter existing.

J. No Release of Indebtedness. Neither Mortgagor, any guarantor, if any, nor any other person hereafter obligated for payment of all or any part of the Indebtedness shall be relieved of such obligation by reason of (a) the failure of Trustee to comply with any request of Mortgagor, or any guarantor or any other person so obligated to foreclose the lien of this Mortgage or to enforce any provision hereunder or under the Credit Agreement; (b) the release, regardless of consideration, of the Mortgaged Property or any portion thereof or interest therein or the addition of any other property to the Mortgaged Property; (c) any agreement or stipulation between any subsequent owner of the Mortgaged Property and Mortgagee extending, renewing, rearranging or in any other way modifying the terms of this Mortgage without first having obtained the consent of, given notice to or paid any consideration to Mortgagor, any guarantor or such other person, and in such event Mortgagor, guarantor and all such other persons shall continue to be liable to make payment according to the terms of any such extension or modification agreement unless expressly released and discharged in writing by Mortgagee; or (d) by any other act or occurrence save and except Security Termination.

K. Release of and Resort to Collateral. Mortgagee may release, regardless of consideration, any part of the Mortgaged Property without, as to the remainder, in any way impairing, affecting, subordinating or releasing the lien or security interest created in or evidenced by this Mortgage or its stature as a first and prior lien and security interest in and to the Mortgaged Property, and without in any way releasing or diminishing the liability of any person or entity liable for the repayment of the Indebtedness. For payment of the Indebtedness, Mortgagee may resort to any other security therefor held by Mortgagee or Trustee in such order and manner as Mortgagee may elect.

L. Waiver of Redemption, Notice and Marshalling of Assets, Etc. To the fullest extent permitted by law, Mortgagor hereby irrevocably and unconditionally waives and releases (a) all benefits that might accrue to Mortgagor by virtue of any present or future moratorium law or other law exempting the Mortgaged Property from attachment, levy or sale on execution or providing for any appraisement, valuation, stay of execution, exemption from civil process, redemption or extension of time for payment; provided, however, that if the laws of any state do not permit the redemption period to be waived, the redemption period is specifically reduced to the minimum amount of time allowable by statute; (b) all notices of any Event of Default or of Mortgagee’s intention to accelerate maturity of the Indebtedness or of Trustee’s election to exercise or his actual exercise of any right, remedy or recourse provided for hereunder or under the Credit Agreement; and (c) any right to a marshalling of assets or a sale in inverse order of alienation. If any law referred to in this Mortgage and now in force, of which Mortgagor or its successor or successors might take advantage despite the provisions hereof, shall hereafter be repealed or cease to be in force, such law shall thereafter be deemed not to constitute any part of the contract herein contained or to preclude the operation or application of the provisions hereof.

 

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M. Discontinuance of Proceedings. In case Mortgagee shall have proceeded to invoke any right, remedy or recourse permitted hereunder or under the Credit Agreement and shall thereafter elect to discontinue or abandon same for any reason, Mortgagee shall have the unqualified right so to do and, in such an event, Mortgagor and Mortgagee shall be restored to their former positions with respect to the Indebtedness, this Mortgage, the Credit Agreement, the Mortgaged Property and otherwise, and the rights, remedies, recourses and powers of Mortgagee shall continue as if same had never been invoked.

N. Application of Proceeds. The proceeds of any sale of the Mortgaged Property or any part thereof and all other monies received by Trustee or Mortgagee in any proceedings for the enforcement hereof or otherwise, whose application has not elsewhere herein been specifically provided for, shall be applied in the order set forth in Section 7.04 of the Guarantee and Collateral Agreement.

O. Resignation of Operator. In addition to all rights and remedies under this Mortgage, at law and in equity, if any Event of Default has occurred and be continuing and Trustee or Mortgagee shall exercise any remedies under this Mortgage with respect to any portion of the Mortgaged Property (or Mortgagor shall transfer any Mortgaged Property in “lieu of foreclosure”), Mortgagee or Trustee shall have the right to request that any operator of any Mortgaged Property that is Mortgagor or any Affiliate of Mortgagor to resign as operator under the joint operating agreement applicable thereto. No later than sixty (60) days after receipt by Mortgagor of any such request, Mortgagor shall resign (or cause such other party to resign) as operator of such Mortgaged Property.

P. INDEMNITY. IN CONNECTION WITH ANY ACTION TAKEN BY TRUSTEE AND/OR MORTGAGEE PURSUANT TO THIS MORTGAGE, TRUSTEE AND/OR MORTGAGEE AND THEIR OFFICERS, DIRECTORS, EMPLOYEES, REPRESENTATIVES, AGENTS, ATTORNEYS, ACCOUNTANTS AND EXPERTS (“INDEMNIFIED PARTIES”) SHALL NOT BE LIABLE FOR ANY LOSS SUSTAINED BY MORTGAGOR RESULTING FROM AN ASSERTION THAT MORTGAGEE HAS RECEIVED FUNDS FROM THE PRODUCTION OF HYDROCARBONS CLAIMED BY THIRD PERSONS OR ANY ACT OR OMISSION OF ANY INDEMNIFIED PARTY IN ADMINISTERING, MANAGING, OPERATING OR CONTROLLING THE MORTGAGED PROPERTY INCLUDING SUCH LOSS WHICH MAY RESULT FROM THE ORDINARY NEGLIGENCE OF AN INDEMNIFIED PARTY UNLESS SUCH LOSS IS CAUSED BY THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF AN INDEMNIFIED PARTY OR IN RESPECT OF ANY PROCEEDING NOT RESULTING FROM AN ACT OR OMISSION BY THE MORTGAGOR OR ITS AFFILIATES, OR THEIR PREDECESSORS IN INTEREST, THAT IS BROUGHT BY AN INDEMNIFIED PARTY AGAINST ANOTHER INDEMNIFIED PARTY, NOR SHALL TRUSTEE AND/OR MORTGAGEE BE OBLIGATED TO PERFORM OR DISCHARGE ANY OBLIGATION, DUTY OR LIABILITY OF MORTGAGOR. MORTGAGOR SHALL AND DOES HEREBY AGREE TO INDEMNIFY EACH INDEMNIFIED PARTY FOR, AND TO HOLD EACH INDEMNIFIED PARTY HARMLESS FROM, ANY AND ALL LIABILITY, LOSS OR DAMAGE WHICH MAY OR MIGHT BE INCURRED BY ANY INDEMNIFIED PARTY BY REASON OF THIS MORTGAGE OR THE EXERCISE OF RIGHTS OR REMEDIES HEREUNDER. SHOULD TRUSTEE AND/OR MORTGAGEE MAKE ANY EXPENDITURE ON ACCOUNT OF ANY SUCH LIABILITY, LOSS OR DAMAGE, THE AMOUNT THEREOF, INCLUDING COSTS, EXPENSES AND REASONABLE ATTORNEYS’ FEES, SHALL BE A DEMAND OBLIGATION (WHICH OBLIGATION MORTGAGOR HEREBY EXPRESSLY PROMISES TO PAY) OWING BY MORTGAGOR TO TRUSTEE AND/OR MORTGAGEE AND SHALL BEAR INTEREST FROM THE DATE EXPENDED UNTIL PAID AT THE DEFAULT RATE, SHALL BE A PART OF THE INDEBTEDNESS AND SHALL BE SECURED BY THIS MORTGAGE AND ANY OTHER SECURITY DOCUMENT.

 

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MORTGAGOR HEREBY ASSENTS TO, RATIFIES AND CONFIRMS ANY AND ALL ACTIONS OF TRUSTEE AND/OR MORTGAGEE WITH RESPECT TO THE MORTGAGED PROPERTY TAKEN UNDER THIS MORTGAGE. THE LIABILITIES OF MORTGAGOR AS SET FORTH IN THIS SECTION 4.16 SHALL SURVIVE THE TERMINATION OF THIS MORTGAGE AND SECURITY TERMINATION.

Q. Default Interest. Interest at a rate equal to that set forth in Section 2.07 of the Credit Agreement shall accrue on any judgment obtained by Mortgagee or Trustee against Mortgagor, whether such judgment is foreclosure of this Mortgage or is a judgment in personam based on the Indebtedness, from the date of judgment until actual payment is made of the full amount of the judgment.

14.

TRUSTEE

A. Duties, Rights, and Powers of Trustee. It shall be no part of the duty of Trustee to see to any recording, filing or registration of this Mortgage or any other instrument in addition or supplemental thereto, or to give any notice thereof, or to see to the payment of or be under any duty in respect of any tax or assessment or other governmental charge that may be levied or assessed on the Mortgaged Property, or any part thereof, or against Mortgagor, or to see to the performance or observance by Mortgagor of any of the covenants and agreements contained herein. Trustee shall not be responsible for the execution, acknowledgment or validity of this Mortgage or of any instrument in addition or supplemental hereto or for the sufficiency of the security purported to be created hereby, and makes no representation in respect thereof or in respect of the rights of Mortgagee. Trustee shall have the right to consult with counsel upon any matters arising hereunder and shall be fully protected in relying as to legal matters on the advice of counsel. Trustee shall not incur any personal liability hereunder except for Trustee’s own willful misconduct and gross negligence, as determined in a final non-appealable judgment of a court of competent jurisdiction. Trustee shall have the right to rely on any instrument, document or signature authorizing or supporting any action taken or proposed to be taken by him hereunder, believed by it in good faith to be genuine.

B. Successor Trustee. Trustee may resign by written notice addressed to Mortgagee or be removed at any time with or without cause by an instrument in writing duly executed on behalf of Mortgagee. In case of the death, resignation or removal of Trustee, a successor trustee may be appointed by Mortgagee by instrument of substitution complying with any applicable requirements of law, or, in the absence of any such requirement, without other formality than appointment and designation in writing. Written notice of such appointment and designation shall be given by Mortgagee to Mortgagor, but the validity of any such appointment shall not be impaired or affected by failure to give such notice or by any defect therein. Such appointment and designation shall be full evidence of the right and authority to make the same and of all the facts therein recited, and, upon the making of any such appointment and designation, this Mortgage shall vest in the successor trustee all the estate and title in and to all of the Mortgaged Property, and the successor trustee shall thereupon succeed to all of the rights, powers, privileges, immunities and duties hereby conferred upon Trustee named herein, and one such appointment and designation shall not exhaust the right to appoint and designate a successor trustee hereunder but such right may be exercised repeatedly as long as any Indebtedness remains unpaid hereunder. To facilitate the administration of the duties hereunder, Mortgagee may appoint multiple trustees to serve in such capacity or in such jurisdictions as Mortgagee may designate.

C. Retention of Moneys. All moneys received by Trustee shall, until used or applied as herein provided, be held in trust for the purposes for which they were received, but need not be segregated in any manner from any other moneys (except to the extent required by law), and Trustee shall be under no liability for interest on any moneys received hereunder.

 

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15.

SECURITY AGREEMENT

A. Security Interest. To further secure the Indebtedness and the performance of the covenants, agreements and obligations of Mortgagor herein, Mortgagor hereby grants to Mortgagee and Mortgagee’s successors and assigns for the ratable benefit of the Beneficiaries, a security interest in all of Mortgagor’s rights, titles and interests in and to the Mortgaged Property insofar as such Mortgaged Property consists of goods, equipment, accounts, contract rights, general intangibles, insurance contracts, insurance proceeds, inventory, Hydrocarbons, as-extracted collateral (including but not limited to all oil, gas, casinghead gas, natural gas liquids, natural gasoline, distillate, liquid hydrocarbons, gaseous hydrocarbons and all products refined therefrom and all other minerals), fixtures and any and all other personal property of any kind or character defined in and subject to the provisions of the Uniform Commercial Code presently in effect in the jurisdiction in which the Mortgaged Property is situated or that otherwise applies to any portion of the Mortgaged Property (the “Applicable UCC”) including without limitation, all accessions, additions, and attachments to any thereof, and the proceeds and products from any and all of such personal property (all of the foregoing being herein collectively called the “Collateral”); provided that, for the avoidance of doubt, “Collateral” shall not mean or include any Excluded Property. Upon the occurrence and during the continuance of any Event of Default, Mortgagee is and shall be entitled to all of the rights, powers and remedies afforded a secured party by the Applicable UCC with regard to the Collateral in which Mortgagee has been granted a security interest herein, or Mortgagee may proceed as to both the real and personal property covered hereby in accordance with the rights and remedies granted under this instrument in respect of the real property covered hereby. Such rights, powers and remedies shall be cumulative and in addition to those granted Mortgagee under any other provision of this instrument or under any other instrument executed in connection with or as security for any of the Indebtedness. Mortgagor, as debtor (and in this Article VI and otherwise herein called “Debtor”) covenants and agrees with Mortgagee, as secured party (and in this Article VI and otherwise herein called “Secured Party”) that:

(1) To the extent permitted by applicable law, Debtor expressly waives any notice of sale or other disposition of the Collateral and any other right or remedies of a Debtor or formalities prescribed by law relative to sale or disposition of the Collateral or exercise of any other right or remedy of Secured Party existing after an Event of Default hereunder; and to the extent any such notice is required and cannot be waived, Debtor agrees that if such notice is mailed to Debtor in accordance with Section 9.01 of the Credit Agreement at least ten (10) days before the time of the sale or disposition, such notice shall be deemed reasonable and shall fully satisfy any requirement for giving of said notice.

(2) If an Event of Default shall have occurred and be continuing, Secured Party is expressly granted the right at its option, to dispose of the Collateral in accordance with the Applicable UCC and to receive the monies, income, proceeds, or benefits attributable or accruing thereto and to hold the same as security for the Indebtedness or to apply it on the principal and interest or other amounts owing on any of the Indebtedness, whether or not then due, in such order or manner as Secured Party may elect. All rights to marshalling of assets of Debtor, including any such right with respect to the Collateral, are hereby waived.

(3) All recitals in any instrument of assignment or any other instrument executed by Secured Party incident to sale, transfer, assignment or other disposition or utilization of the Collateral or any part thereof hereunder shall be prima facie evidence of the matter stated therein, no other proof shall be required to establish full legal propriety of the sale or other action or of any fact, condition or thing incident thereto, and all prerequisites of such sale or other action and of any fact, condition or thing incident thereto shall be presumed to have been performed or to have occurred.

 

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(4) All expenses of preparing for sale, or other use or disposition, selling or otherwise using or disposing of the Collateral and the like which are incurred or paid by Secured Party as authorized or permitted hereunder, including also all reasonable attorneys’ fees, legal expenses and costs, shall be added to the Indebtedness and Debtor shall be liable therefor.

(5) Should Secured Party elect to exercise its rights under the Applicable UCC as to part of the Collateral, this election shall not preclude Secured Party from exercising any other rights and remedies granted by this instrument as to the remainder of the Collateral.

(6) Any copy of this instrument may also serve as a financing statement under the Applicable UCC between the Debtor, whose present address is Mortgagor’s address listed on the execution page of this Mortgage, and Secured Party, whose present address is Mortgagee’s address listed on the execution page of this Mortgage.

(7) Secured Party is authorized to file, in any applicable jurisdiction where Secured Party deems it necessary to perfect or to maintain the perfection of any security interest granted under this Mortgage, a financing statement or statements describing the Collateral, and at the request of Secured Party, Debtor will join Secured Party in delivering one or more financing statements pursuant to the Applicable UCC in form reasonably satisfactory to Secured Party, and will pay the reasonable cost of filing or recording this instrument, as a financing statement, in all public offices at any time and from time to time whenever filing or recording of any financing statement or of this instrument is deemed by Secured Party to be necessary to perfect or to maintain the perfection of any security interest granted under this Mortgage.

(8) The office where Debtor keeps Debtor’s accounting records concerning the Collateral covered by this Security Agreement is the address set forth for Mortgagor on the execution page of this Mortgage or such other address as disclosed in writing to Secured Party in accordance herewith.

B. As Extracted Collateral and Fixtures. Portions of the Collateral consist of (i) oil, gas and other minerals produced or to be produced from the lands described in the Leases (as extracted collateral), or (ii) goods which are or will become fixtures attached to the real estate constituting a portion of the Mortgaged Property, and Debtor hereby agrees that this instrument shall be filed in the real estate records of the Counties in which the Mortgaged Property is located as a financing statement to perfect the security interest of Secured Party in said portions of the Collateral. The said oil, gas and other minerals will be financed at the wellhead of the oil and gas wells located on the lands described in the Leases. The name of the record owner of the Mortgaged Property is the party named herein as Mortgagor and Debtor. Nothing herein contained shall impair or limit the effectiveness of this document as a security agreement or financing statement for other purposes.

16.

Miscellaneous

A. Instrument Construed as Mortgage, Etc. With respect to any portions of the Mortgaged Property located in any state or other jurisdiction the laws of which do not provide for the use or enforcement of a deed of trust or the office, rights and authority of Trustee as herein provided, the general language of conveyance hereof to Trustee is intended and the same shall be construed as words of mortgage unto and in favor of Mortgagee and the rights and authority granted to Trustee herein may be enforced and asserted by Mortgagee in accordance with the laws of the jurisdiction in which such portion of the Mortgaged Property is located and the same may be foreclosed at the option of Mortgagee as to any

 

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or all such portions of the Mortgaged Property, in any manner permitted by the laws of the jurisdiction in which such portions of the Mortgaged Property is situated. This Mortgage may be construed as a mortgage, deed of trust, chattel mortgage, conveyance, assignment, security agreement, pledge, financing statement, hypothecation or contract, or any one or more of them, in order fully to effectuate the lien hereof and the purposes and agreements herein set forth.

B. Release of Mortgage. At such time at which each of the following events shall have occurred on or prior to such time: (i) the Indebtedness (other than (i) indemnity obligations not yet due and payable of which the Borrower has not received a notice of potential claim), (ii) any Obligations not then due and payable under any Cash Management Agreement with a Lender, an Agent, an Arranger or an Affiliate of any of the foregoing, and (iii) Obligations arising under any Secured Hedging Agreement (as defined in the Guarantee and Collateral Agreement) with any Secured Hedge Provider (as defined in the Guarantee and Collateral Agreement) to which other arrangements satisfactory to the applicable Loan Party and the applicable Secured Hedge Provider have been made) are paid in full in cash (including interest accruing during the pendency of an insolvency or liquidation proceeding, regardless of whether allowed or allowable in such insolvency or liquidation proceeding) and premium, if any, on all Loans outstanding under the Credit Agreement and (ii) the Credit Agreement is terminated (“Security Termination”), Mortgagee shall forthwith cause satisfaction and discharge of this Mortgage to be entered upon the record at the expense of Mortgagor and shall execute and deliver or cause to be executed and delivered such instruments of satisfaction and reassignment as may be appropriate. Otherwise, this Mortgage shall remain and continue in full force and effect. If any of the Collateral or Mortgaged Property shall be sold, transferred or otherwise disposed of by the Mortgagor in a transaction expressly permitted by the Credit Agreement, then the Mortgagee, at the request and sole cost and expense of the Mortgagor, shall execute and deliver to the Mortgagor all releases or other documents necessary or reasonably desirable for the release of the liens and security interest created hereby on such Collateral or Mortgaged Property permitted to be so sold or disposed.

C. Severability. If any provision hereof is invalid or unenforceable in any jurisdiction, the other provisions hereof shall remain in full force and effect in such jurisdiction and the remaining provisions hereof shall be liberally construed in favor of Trustee and Mortgagee in order to effectuate the provisions hereof, and the invalidity or unenforceability of any provision hereof in any jurisdiction shall not affect the validity or enforceability of any such provision in any other jurisdiction.

D. Successors and Assigns of Parties. The term “Mortgagee” as used herein shall mean and include any legal owner, holder, assignee or pledgee of the Collateral Agent under the Credit Agreement. The terms used to designate Trustee, Mortgagee and Mortgagor shall be deemed to include the respective heirs, legal representatives, successors and assigns of such parties.

E. Satisfaction of Prior Encumbrance. To the extent that proceeds of the Credit Agreement are used to pay indebtedness secured by any outstanding lien, security interest, charge or prior encumbrance against the Mortgaged Property, such proceeds have been advanced by the Mortgagee at Mortgagor’s request, and Mortgagee shall be subrogated to any and all rights, security interests and liens owned by any owner or holder of such outstanding liens, security interests, charges or encumbrances, irrespective of whether said liens, security interests, charges or encumbrances are released, and it is expressly understood that, in consideration of any such payment of such other indebtedness by the Mortgagee, Mortgagor hereby waives and releases all demands and causes of action for offsets and payments to, upon and in connection with the said indebtedness.

F. Subrogation of Trustee. This Mortgage is made with full substitution and subrogation of Trustee and his successors in this trust and its and their assigns in and to all covenants and warranties by others heretofore given or made in respect of the Mortgaged Property or any part thereof.

 

20


G. Nature of Covenants. The covenants and agreements herein contained shall constitute covenants running with the land and interests covered or affected hereby and shall be binding upon the heirs, legal representatives, successors and assigns of the parties hereto.

H. Notices. All notices, requests, consents, demands and other communications required or permitted hereunder shall be given or furnished in the manner provided under the Credit Agreement.

I. Time. Time shall be of the essence in this Mortgage.

J. Counterparts. This Mortgage is being executed in several counterparts, all of which are identical, except that to facilitate recordation, if the Mortgaged Property is situated in more than one jurisdiction, descriptions of only those portions of the Mortgaged Property located in, the jurisdiction in which a particular counterpart is recorded shall be attached as Exhibit A thereto. Each of such counterparts shall for all purposes be deemed to be an original and all such counterparts shall together constitute but one and the same instrument.

K. GOVERNING LAW. THIS MORTGAGE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK, EXCEPT TO THE EXTENT THAT THE LAWS OF ANY OTHER JURISDICTION MANDATORILY GOVERN THE ATTACHMENT, CREATION, VALIDITY, PRIORITY, PERFECTION OR MANNER OR PROCEDURE FOR ENFORCEMENT OF THE LIENS OR SECURITY INTERESTS CREATED BY THIS MORTGAGE; PROVIDED, HOWEVER, ANY REMEDIES PROVIDED IN THIS MORTGAGE WHICH ARE VALID UNDER THE LAWS OF THE JURISDICTION WHERE PROCEEDINGS FOR THE ENFORCEMENT OF THIS MORTGAGE ARE TAKEN SHALL NOT BE AFFECTED BY ANY INVALIDITY UNDER THE LAWS OF THE STATE OF NEW YORK.

L. EXCULPATION PROVISIONS. EACH OF THE PARTIES HERETO SPECIFICALLY AGREES THAT IT (A) HAS A DUTY TO READ THIS MORTGAGE AND THAT IT IS CHARGED WITH NOTICE AND KNOWLEDGE OF THE TERMS OF THIS MORTGAGE; (B) HAS IN FACT READ THIS MORTGAGE AND IS FULLY INFORMED AND HAS FULL NOTICE AND KNOWLEDGE OF THE TERMS, CONDITIONS AND EFFECTS OF THIS MORTGAGE; (C) HAS BEEN REPRESENTED BY INDEPENDENT LEGAL COUNSEL OF ITS CHOICE THROUGHOUT THE NEGOTIATIONS PRECEDING ITS EXECUTION OF THIS MORTGAGE, AND HAS RECEIVED THE ADVICE OF ITS ATTORNEY IN ENTERING INTO THIS MORTGAGE; AND (D) RECOGNIZES THAT CERTAIN OF THE TERMS OF THIS MORTGAGE RESULT IN ONE PARTY ASSUMING THE LIABILITY INHERENT IN SOME ASPECTS OF THE TRANSACTION AND RELIEVING THE OTHER PARTY OF ITS RESPONSIBILITY FOR SUCH LIABILITY. EACH PARTY HERETO AGREES AND COVENANTS THAT IT WILL NOT CONTEST THE VALIDITY OR ENFORCEABILITY OF ANY EXCULPATORY PROVISION OF THIS MORTGAGE ON THE BASIS THAT THE PARTY HAD NO NOTICE OR KNOWLEDGE OF SUCH PROVISION OR THAT THE PROVISION IS NOT “CONSPICUOUS.”

[Signature page follows]

 

21


Exhibit H

to the Credit Agreement

IN WITNESS WHEREOF, this Mortgage is executed as of the date written in the acknowledgement block below, but effective for all purposes as of the Effective Date.

 

MORTGAGOR:

Energy & Exploration Partners, LLC,

a Delaware limited liability company

By:  

/s/ Tom D. McNutt

  Tom D. McNutt
  Executive Vice President, General Counsel and Secretary

 

STATE OF TEXAS    §
   §
COUNTY OF HARRIS    §

This instrument was acknowledged before me this 22nd day of July, 2014 by Tom D. McNutt, the Executive Vice President, General Counsel and Secretary of Energy & Exploration Partners, LLC, a Delaware limited liability company, on behalf of said company.

In witness whereof I hereunto set my hand and official seal.

 

NOTARIAL SEAL:    

 

      Notary Public
My Commission Expires:                                                                               
The name and address of Mortgagor/Debtor is:     The name and address of Mortgagee/Secured Party is:
ENERGY & EXPLORATION PARTNERS, LLC     CREDIT SUISSE AG, CAYMAN ISLANDS BRANCH

Attn: Tom McNutt

Two City Place, 100 Throckmorton, Suite 1700,

Fort Worth, Texas 76102

Telephone: (817) 789-6712

Facsimile: (817) 315-9811

   

Eleven Madison Avenue

23rd Floor

New York, NY 10010

Attn: Loan Operations – Boutique Management

Signature Page to Mortgage


Exhibit H

to the Credit Agreement

EXHIBIT A

DEFINITIONS:

1. The terms used on Exhibit A have the same meaning as defined in the Mortgage.

2. The term “Permitted Encumbrances” shall mean (i) Liens expressly permitted by Section 6.02 of the Credit Agreement; and (ii) the specific exceptions and encumbrances affecting any of the Mortgaged Property as described on Exhibit A INSOFAR ONLY as said exceptions and encumbrances are valid and subsisting and are enforceable against the particular Lease or Easement which is made subject to said exceptions and encumbrances.

3. With respect to the descriptions of each of the Mortgaged Property, if the description requires, such description may continue on several successive pages of each Part of Exhibit A. Certain property descriptions are in abbreviated form as to Sections, Townships and Ranges. In such descriptions the following terms may be abbreviated as follows:

 

Northwest Quarter as    NW, NW/4 or NW1/4;
Southwest Quarter as    SW, SW/4 or SW1/4;
Southeast Quarter as    SE, SE/4 or SE1/4;
Northeast Quarter as    NE, NE/4 or NE1/4;
North Half as    N/2 or N1/2;
South Half as    S/2 or S1/2;
East Half as    E/2 or E1/2; and
West Half as    W/2 or W1/2.

The applicable Section, Township and Range may be identified by a series of three numbers, each separated by a dash, with the first number being the Section number, the second number being the Township number and the third number being the Range number. The Township and Range numbers are followed by an N, S, E or W to indicate whether the Township or Range is North, South, East or West, respectively. In some instances, the Section number may be stated by itself and not in conjunction with a series of dashed numbers representing the appropriate Township and Range, e.g., the description “N/2 14, SESW 21 29N 8W” means “North one half of Section 14 and Southeast quarter of Southwest quarter of Section 21, all in Township 29 North, Range 8 West.” Certain descriptions merely refer to the subdivision or survey in which the property is located in whole or in part. In such cases, the recorded Leases and any amendments thereof and any other recorded instruments affecting Mortgagor’s title more particularly describe the land within such subdivision or survey in which Mortgagor owns an interest, and the descriptions contained in such instruments are incorporated herein by this reference.

4. The term “API” shall mean that certain American Petroleum Institute number assigned to an oil and gas well by the relevant state regulatory agency (such as the Texas Railroad Commission) and maintained in the public files of such agency.

SYMBOLS AND ABBREVIATIONS:

1. The abbreviation “BPO” or the term “before payout” as used herein means that the figure next to which this abbreviation appears represents Mortgagor’s net income interest until such time as the operator of the well or wells situated on the described property has recovered from production from that well or those wells all costs as specified in underlying farmout assignments or other documents in the chain of title, usually including costs of drilling, completing and equipping a well or wells plus costs of operating the well or wells during the recoupment period.


Exhibit H

to the Credit Agreement

2. The abbreviation “APO” or the term “after payout” as used herein means that the figure next to which this abbreviation appears represents Mortgagor’s net income interest after the point in time when the operator of the well or wells situated on the described property has recovered from production from that well or those wells all costs as specified in underlying farmout assignments or other documents in the chain of title, usually including costs of drilling, completing and equipping a well or wells plus costs of operating the well or wells during the recoupment period.

*****

NOTWITHSTANDING ANYTHING HEREIN TO THE CONTRARY, THIS MORTGAGE COVERS ALL OF MORTGAGOR’S INTERESTS IN AND TO THE OIL, GAS AND MINERAL LEASES DESCRIBED ON EXHIBIT A, INCLUDING WITHOUT LIMITATION, THE LANDS DESCRIBED ON EXHIBIT A BY METES AND BOUNDS LOCATED THEREON, IF ANY.



Exhibit 10.9

ENERGY & EXPLORATION PARTNERS, INC.

2012 STOCK INCENTIVE PLAN

THIRD AMENDMENT TO RESTRICTED STOCK AWARD AGREEMENT

THIS THIRD AMENDMENT TO RESTRICTED STOCK AWARD AGREEMENT, dated as of March 31, 2014 (this “Amendment”), is made by and between Energy & Exploration Partners, Inc., a Delaware corporation (the “Company”), and Brian Nelson (the “Participant”). Capitalized terms used herein but not otherwise defined shall have the meanings ascribed thereto in the Agreement (as defined below).

RECITALS:

WHEREAS, the Company adopted the Energy & Exploration Partners, Inc. 2012 Stock Incentive Plan (the “Plan”) pursuant to which awards of Restricted Stock of the Company may be granted; and

WHEREAS, the Company and the Participant entered into that certain Restricted Stock Award Agreement , dated August 22, 2012 (the “Agreement”); and

WHEREAS, the Company and the Participant entered into that certain First Amendment to Restricted Stock Award Agreement, dated November 16, 2012, for the purpose of amending certain terms and provisions of the Agreement; and

WHEREAS, the Company and the Participant entered into that certain Second Amendment to Restricted Stock Award Agreement, dated December 1, 2013, for the purpose of amending certain terms and provisions of the Agreement; and

WHEREAS, the Committee has determined that it is in the best interests of the Company and its stockholders to enter into this Amendment with the Participant in recognition of the Participant’s services to the Company and to align the Participant’s and Company’s interests, subject to the terms set forth herein.

NOW, THEREFORE, in consideration for the services rendered by the Participant to the Company and the mutual covenants hereinafter set forth, the parties hereto agree as follows:

I. AMENDMENTS

 

1. The first paragraph of Section 4 is hereby deleted in its entirety and replaced with the following:

“4. Vesting. Except as otherwise provided herein, the restrictions described in Section 3 above will lapse with respect to all of the Restricted Shares on the date set forth herein (the “Vesting Date,” and, with respect to each Restricted Share, the period beginning on the Date of Grant and ending on the Vesting Date for such share, the “Restricted Period”); provided that the Participant is still in Continuous Service with the Company on such Vesting Date. The Vesting Date shall be August 15, 2014. On the Vesting Date, the restrictions described in Section 3 above will lapse with respect to 100% of the Restricted Shares.”


II. MISCELLANEOUS

(a) Governing Law. This Amendment shall be construed and interpreted in accordance with the laws of the State of Delaware without regard to principles of conflicts of law thereof, or principles of conflicts of laws of any other jurisdiction that could cause the application of the laws of any jurisdiction other than the State of Delaware.

(a) Severability. Every provision of this Amendment is intended to be severable and any illegal or invalid term shall not affect the validity or legality of the remaining terms.

(b) Headings. The headings of the Sections hereof are provided for convenience only and are not to serve as a basis for interpretation of construction, and shall not constitute a part of this Amendment.

(c) Effect of Amendment; Agreement Continuation. Except as amended hereby, all other terms and conditions of the Agreement shall remain the same and in full force and effect. The Agreement, as modified herein, shall continue in full force and effect, and nothing herein contained shall be construed as a modification of existing rights under the Agreement, except as such rights are expressly modified hereby.

(d) Counterparts. This Amendment may be signed in counterparts (including by facsimile transmission), each of which shall be deemed an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

[Signature page follows]

 

-2-


IN WITNESS WHEREOF, the parties hereto have executed this Amendment as of the day first written above.

 

ENERGY & EXPLORATION PARTNERS, INC.
By:  

/s/ Hunt Pettit

Name: Hunt Pettit
Title: President and Chief Executive Officer

The undersigned hereby accepts the terms of this Amendment.

 

/s/ Brian Nelson

Brian Nelson

Signature page to Third Amendment to Restricted Stock Award Agreement



Exhibit 21.1

Subsidiaries of Energy & Exploration Partners, Inc.

 

Company:

   Jurisdiction of Organization:

Energy & Exploration Partners, LLC

   Delaware

Energy & Exploration Partners Operating GP, LLC

   Texas

Energy & Exploration Partners Operating, LP

   Texas

H2 Midstream LLC

   Delaware


Exhibit 23.1

 

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

We consent to the use in this Registration Statement on Form S-1 of Energy & Exploration Partners, Inc. of our report, which is dated April 4, 2014, relating to our audits of the consolidated financial statements, appearing in the Prospectus, which is part of this Registration Statement.

 

We also consent to the reference to our firm under the caption “Experts” in the Prospectus.

 

/s/ Hein & Associates LLP

 

Dallas, Texas

September 12, 2014



Exhibit 23.3

 

CAWLEY, GILLESPIE & ASSOCIATES, INC.

 

PETROLEUM CONSULTANTS

 

13640 BRIARWICK DRIVE, SUITE 100   306 WEST SEVENTH STREET, SUITE 302   1000 LOUISIANA STREET, SUITE 625
AUSTIN, TEXAS 78729-1707   FORT WORTH, TEXAS 76102-4987   HOUSTON, TEXAS 77002-5008
512-249-7000   817- 336-2461   713-651-9944
  WWW.CGAUS.COM  

 

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS

 

Board of Directors

Energy & Exploration Partners, Inc.

Fort Worth, Texas

 

We hereby consent to the references to Cawley, Gillespie & Associates, to the inclusion of our estimates of reserves contained in our reports entitled “Evaluation Summary, Energy & Exploration Partners, LLC Interests, Grimes, Leon and Madison Counties, Texas, Proved Reserves, As of June 1, 2014” and “Evaluation Summary, Energy & Exploration Partners, LLC Interests, Grimes, Leon, and Madison Counties, Texas, Proved Reserves, As of December 31, 2013” and “Evaluation Summary, Energy & Exploration Partners, LLC Interests, Colorado and Texas, Proved Developed Producing Reserves, As of December 31, 2012” and to the specific references to Cawley, Gillespie & Associates as the independent petroleum engineering firm in this Form S-1 Registration Statement and any amendments thereto (collectively, the “Registration Statement”) and the prospectus to which the Registration Statement is related. We further consent to the inclusion of our letter reports dated June 13, 2014, March 27, 2014 and January 7, 2013 as exhibits to the Registration Statement.

 

Yours truly,

 

CAWLEY, GILLESPIE & ASSOCIATES, INC.

LOGO

 

Fort Worth, Texas

September 12, 2014



Exhibit 23.4

 

LOGO

 

CONSENT OF INDEPENDENT ACCOUNTING FIRM

 

We consent to the use in this Registration Statement on Form S-1 of Energy & Exploration Partners, Inc. of our report, which is dated March 19, 2014, relating to our audits of the financial statements of TreadStone Energy Partners, LLC, appearing in the Prospectus, which is part of this Registration Statement.

 

We also consent to the reference to our firm under the caption “Experts” in the Prospectus.

 

LOGO

 

Covington, LA

September 12, 2014

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

LOGO



Exhibit 23.5

 

CAWLEY, GILLESPIE & ASSOCIATES, INC.

 

PETROLEUM CONSULTANTS

 

13640 BRIARWICK DRIVE, SUITE 100   306 WEST SEVENTH STREET, SUITE 302   1000 LOUISIANA STREET, SUITE 625
AUSTIN, TEXAS 78729-1707   FORT WORTH, TEXAS 76102-4987   HOUSTON, TEXAS 77002-5008
512-249-7000   817- 336-2461   713-651-9944
  WWW.CGAUS.COM  

 

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS

 

Board of Directors

Energy & Exploration Partners, Inc.

Fort Worth, Texas

 

We hereby consent to the references to Cawley, Gillespie & Associates, to the inclusion of our estimates of reserves contained in our reports entitled “Evaluation Summary, Treadstone Energy Partners Acquisition Interests, Houston and Madison Counties, Texas, Proved Reserves, As of June 1, 2014” and to the specific references to Cawley, Gillespie & Associates as the independent petroleum engineering firm in this Form S-1 Registration Statement and any amendments thereto (collectively, the “Registration Statement”) and the prospectus to which the Registration Statement is related. We further consent to the inclusion of our letter reports dated June 16, 2014 as exhibits to the Registration Statement.

 

Yours truly,

 

CAWLEY, GILLESPIE & ASSOCIATES, INC.

LOGO

 

Fort Worth, Texas

September 12, 2014



Exhibit 99.1

 

LOGO

 

September 12, 2014

 

Reference is made to the registration statement on Form S-1 to be filed with the U.S. Securities and Exchange Commission pursuant to the Securities Act of 1933, as amended (the “Registration Statement”), relating to the initial public offering of shares of common stock of Energy & Exploration Partners, Inc. (the “Company”). We hereby consent to all references to our name in the Registration Statement and to the use of the statistical information supplied and reviewed by us set forth in the sections of the Registration Statement entitled “Prospectus Summary—Our Operating Areas— East Texas Stacked Play” and “Business—Our Operating Areas—East Texas Stacked Play.” We further advise the Company, its underwriters and legal counsel that our role has been limited to the provision of such statistical data supplied by us.

 

With respect to such statistical data, we advise you that:

 

   

some information in our database is derived from estimates or subjective judgments;

 

   

the information has been compiled from our internal sources and public documents, which we believe to be reliable and in good faith.

 

We hereby consent to the filing of this letter as an exhibit to the Registration Statement.

 

In giving this consent, we do not thereby admit that we are included in the category of persons whose consent is required under Section 7 of the Securities Act or the rules and regulations of the Securities and Exchange Commission.

 

DRILLING INFO, INC.

By:

 

/s/ Shawn M. Shillington

Name: Shawn M. Shillington

Title: Secretary and Assistant General Counsel



Exhibit 99.4

CAWLEY, GILLESPIE & ASSOCIATES, INC.

PETROLEUM CONSULTANTS

 

13640 BRIAR WICK DRIVE, SUITE 100

AUSTIN, TEXAS 78729-1707

512-249-7000

  

306 WEST SEVENTH STREET, SUITE 302

FORT WORTH, TEXAS 76102-4987

817- 336-2461

www.cgaus.com

  

1000 LOUISIANA STREET, SUITE 625

HOUSTON, TEXAS 77002-5008

713-651-9944

June 13, 2014

Mr. Hunt Pettit

Energy & Exploration Partners, LLC

Two City Place, Suite 1700

100 Throckmorton Street

Fort Worth, Texas 76102

 

Re:   Evaluation Summary
  Energy & Exploration Partners, LLC Interests
  Grimes, Leon, and Madison Counties, Texas
  Proved Reserves
  As of June 1, 2014

Dear Mr. Pettit:

As requested, we are submitting this report, completed June 12, 2014, of the estimates of the proved reserves, and the forecasts of the resulting economics effective as of June 1, 2014 attributable to the Energy & Exploration Partners, LLC interests in certain properties located in Grimes, Leon and Madison Counties, Texas. We understand that this report may be used for IRS or SEC purposes. This report has been prepared for Energy & Exploration Partners, LLC pursuant to the rules, regulations and guidelines of the Securities and Exchange Commission, Item 1202 (a) (8) of Regulation S-K, for reporting corporate reserves and future net revenue. The results of these evaluations are summarized below:

 

     Total
Proved
     Proved
Developed
Producing
     Proved
Developed
Non-Producing
     Proved
Undeveloped
 

Net Reserves

           

Oil, Mbbl

     7,483.5         1,777.0         121.0         5,585.5   

Gas, MMcf

     5,609.6         2,019.1         282.7         3,307.8   

NGL,Mbbl

     756.7         213.1         43.6         500.1   

Net Revenue

           

Oil, M$

     741,731.6         176,048.2         11,997.5         553,685.9   

Gas, M$

     21,096.1         7,593.3         1,063.2         12,439.5   

NGL,M$

     21,356.6         6,013.2         1,229.7         14,113.7   

Production Taxes, M$

     37,303.6         9,118.7         723.9         27,461.0   

Ad Valorem Taxes, M$

     18,671.1         4,512.5         339.2         13,819.5   

Operating Expenses, M$

     157,331.8         46,297.4         3,782.1         107,252.2   

Investments, M$

     159,654.2         117.6         21,800.0         156,736.5   

Future Net Cash Flow, M$

     411,223.4         129,608.2         6,645.3         274,969.9   

10% Discounted Cash Flow, M$

     205,719.0         85,224.9         3,780.2         116,713.8   


Mr. Hunt Pettit

Energy & Exploration Partners, LLC Interests

SEC Price Case

June 13, 2014

Page 2

 

The discounted cash flow value shown above should not be construed to represent an estimate of fair market value by Cawley, Gillespie & Associates, Inc. In accordance with the Securities and Exchange Commission guidelines, the future net cash flow, operating income (BFIT), has been discounted at an annual rate of 10% to determine its “present worth”. The discounted value, “present worth”, is indicative of the time value of money.

As to the assumptions, methods and procedures used in connection with the preparation of this report, prices were forecast in accordance with Securities and Exchange Commission rules and guidelines. The prices are determined as an unweighted arithmetic average of the first-day-of-the-month benchmark price for each of the twelve months prior to the effective date June 1, 2014. The 12-month average benchmark Henry Hub spot gas price of $4.07 per MMBtu and the 12-month average benchmark WTI Cushing spot oil price of $99.38 per barrel (source: INO.com) were used. The oil and gas prices were held constant throughout the life of the properties. The prices were adjusted for gravity, quality, heating value, shrinkage, transportation and marketing. For these properties, the resulting oil and gas prices are $99.115 per barrel and $3.761 per MCF, respectively. The resulting plant products price is $28.224 per barrel.

For these properties, the proved producing reserves are forecast using the production performance and analogy methods. The proved non-producing and undeveloped reserves are forecast using the analogy method. An on-site field inspection of the properties has not been performed. The mechanical operation or conditions of the wells and their related facilities have not been examined nor have the wells been tested by Cawley, Gillespie & Associates, Inc. Possible environmental liability related to the properties has not been investigated nor considered.

The reserve classifications conform to the definitions and criteria of the Securities and Exchange Commission. The reserves and economics are predicated on the regulatory agency classifications, rules, policies, laws, taxes and royalties in effect on the effective date except as noted herein. The possible effects of changes in legislation or other Federal or State restrictive actions which could affect the reserves and economics have not been considered. We are not aware of any legislative changes or restrictive actions that may possibly impact the reserves or economics as presented. Possible environmental liability related to the properties has not been investigated nor considered. The assumptions, data, methods and procedures as described are appropriate for the purpose of this report. All reserve estimates represent our best judgment based on data available at the time of preparation and assumptions as to future economic and regulatory conditions. Due to the inherent uncertainties of reserves estimates, future production rates, commodity prices, costs and expenses, it should be realized that the reserves actually recovered, the revenue received and the actual cost incurred could be more or less than the estimated amounts.

The reserves estimates were based on interpretations of factual data furnished by your office or Energy & Exploration Partners, LLC. Oil and gas prices, pricing differentials, expense and cost data, tax values, the subject wells and ownership interests were supplied by you or Energy & Exploration Partners, LLC and were accepted as furnished. To some extent, information from public records has been used to check or supplement these data. The basic engineering and geological data were subject to third party reservations and qualifications. Nothing has come to our attention, however, that would cause us to believe that we are not justified in relying on such data. We have used all methods and procedures that we consider necessary under the circumstances to prepare this report.

 


Mr. Hunt Pettit

Energy & Exploration Partners, LLC Interests

SEC Price Case

June 13, 2014

Page 3

 

Cawley, Gillespie & Associates, Inc. is independent with respect to Energy & Exploration Partners, LLC as provided in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserve Information promulgated by the Society of Petroleum Engineers. Neither Cawley, Gillespie & Associates, Inc. nor any of its employees has any interest in the subject properties. Neither the employment to make this study nor the compensation is contingent on the results of our work or the future performance of the subject properties. Cawley, Gillespie and Associates, Inc. is a Texas registered engineering firm, F-693, of professional engineers and geologists serving the oil and gas industry for over fifty years.

This report was prepared for the use of Energy & Exploration Partners, LLC. This letter should not be used, circulated or quoted for any other purpose without your express written consent and that of Cawley, Gillespie & Associates, Inc. or except as required by law. Our work papers and related data are available for inspection and review by authorized, interested parties.

Respectively Submitted,

CAWLEY, GILLESPIE & ASSOCIATES, INC.

Texas Registered Engineering Firm F-693

 

LOGO

Kenneth J. Mueller, PE 86132

Vice· President



Exhibit 99.5

CAWLEY, GILLESPIE & ASSOCIATES, INC.

PETROLEUM CONSULTANTS

 

13640 BRIARWICK DRIVE, SUITE 100

   306 WEST SEVENTH STREET, SUITE 302    1000 LOUISIANA STREET, SUITE 625

AUSTIN, TEXAS 78729-1707

   FORT WORTH, TEXAS 76102-4987    HOUSTON, TEXAS 77002-5008

512-249-7000

   817- 336-2461    713-651-9944
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June 16, 2014

Mr. Hunt Pettit

Energy & Exploration Partners, LLC

Two City Place, Suite 1700

100 Throckmorton Street

Fort Worth, Texas 76102

 

Re:  

Evaluation Summary

Treadstone Energy Partners Acquisition Interests

Houston and Madison Counties, Texas

Proved Reserves

As of June 1, 2014

 

Dear Mr. Pettit:

As requested, we are submitting this report, completed June 13, 2014, of the estimates of the proved reserves, and the forecasts of the resulting economics effective as of June 1, 2014 attributable to the Treadstone Energy Partners interests in certain properties located in Houston and Madison Counties, Texas. We understand that this report may be used for IRS or SEC purposes. This report has been prepared for Energy & Exploration Partners, LLC pursuant to the rules, regulations and guidelines of the Securities and Exchange Commission, Item 1202 (a) (8) of Regulation S-K, for reporting corporate reserves and future net revenue. The results of these evaluations are summarized below:

 

     Total
Proved
     Proved
Developed
Producing
     Proved
Developed
Non-Producing
     Proved
Undeveloped
 

Net Reserves

           

Oil, Mbbl

     25,277.4         4,478.1         2,275.5         18,523.8   

Gas, MMcf

     22,492.3         4,604.2         1,716.8         16,171.3   

NGL, Mbbl

     3,701.8         762.8         296.3         2,642.7   

Net Revenue

           

Oil, M$

     2,580,600.0         457,218.7         232,355.8         1,891,025.4   

Gas, M$

     101,979.5         20,875.2         7,784.1         73,320.2   

NGL, M$

     168,121.2         34,643.4         13,455.5         120,022.3   

Production Taxes, M$

     138,965.2         25,196.0         12,281.3         101,487.9   

Ad Valorem Taxes, M$

     67,793.4         12,188.5         6,032.9         49,572.0   

Operating Expenses, M$

     338,330.7         65,225.3         27,036.1         246,069.4   

Investments, M$

     312,982.1         0.0         17,116.9         295,865.1   

Future Net Cash Flow, M$

     1,992,629.9         410,127.5         191,128.1         1,391,374.5   

10% Discounted Cash Flow, M$

     1,208,043.9         269,577.5         127,432.1         811,034.9   


Mr. Hunt PettitSecurities and Exchange Commission

Treadstone Energy Partners Acquisition Interests

SEC Price Case

June 16, 2014

Page 2

 

The discounted cash flow value shown above should not be construed to represent an estimate of fair market value by Cawley, Gillespie & Associates, Inc. In accordance with the Securities and Exchange Commission guidelines, the future net cash flow, operating income (BFIT), has been discounted at an annual rate of 10% to determine its “present worth”. The discounted value, “present worth”, is indicative of the time value of money.

As to the assumptions, methods and procedures used in connection with the preparation of this report, prices were forecast in accordance with Securities and Exchange Commission rules and guidelines. The prices are determined as an unweighted arithmetic average of the first-day-of-the-month benchmark price for each of the twelve months prior to the effective date June 1, 2014. The 12-month average benchmark Henry Hub spot gas price of $4.07 per MMBtu and the 12-month average benchmark WTI Cushing spot oil price of $99.38 per barrel (source: INO.com) were used. The oil and gas prices were held constant throughout the life of the properties. The prices were adjusted for gravity, quality, heating value, shrinkage, transportation and marketing. For these properties, the resulting oil and gas prices are $102.091 per barrel and $4.534 per MCF, respectively. The resulting plant products price is $45.417 per barrel.

For these properties, the proved producing reserves are forecast using the production performance and analogy methods. The proved non-producing and undeveloped reserves are forecast using the analogy method. An on-site field inspection of the properties has not been performed. The mechanical operation or conditions of the wells and their related facilities have not been examined nor have the wells been tested by Cawley, Gillespie & Associates, Inc. Possible environmental liability related to the properties has not been investigated nor considered.

The reserve classifications conform to the definitions and criteria of the Securities and Exchange Commission. The reserves and economics are predicated on the regulatory agency classifications, rules, policies, laws, taxes and royalties in effect on the effective date except as noted herein. The possible effects of changes in legislation or other Federal or State restrictive actions which could affect the reserves and economics have not been considered. We are not aware of any legislative changes or restrictive actions that may possibly impact the reserves or economics as presented. Possible environmental liability related to the properties has not been investigated nor considered. The assumptions, data, methods and procedures as described are appropriate for the purpose of this report. All reserve estimates represent our best judgment based on data available at the time of preparation and assumptions as to future economic and regulatory conditions. Due to the inherent uncertainties of reserves estimates, future production rates, commodity prices, costs and expenses, it should be realized that the reserves actually recovered, the revenue received and the actual cost incurred could be more or less than the estimated amounts.

The reserves estimates were based on interpretations of factual data furnished by your office, Energy & Exploration Partners, LLC, or Treadstone Energy Partners. Oil and gas prices, pricing differentials, expense and cost data, tax values, the subject wells and ownership interests were supplied by you, Energy & Exploration Partners, LLC, or Treadstone Energy Partners and were accepted as furnished. To some extent, information from public records has been used to check or supplement these data. The basic engineering and geological data were subject to third party reservations and qualifications. Nothing has come to our attention, however, that would cause us to


Mr. Hunt PettitSecurities and Exchange Commission

Treadstone Energy Partners Acquisition Interests

SEC Price Case

June 16, 2014

Page 3

 

believe that we are not justified in relying on such data. We have used all methods and procedures that we consider necessary under the circumstances to prepare this report.

Cawley, Gillespie & Associates, Inc. is independent with respect to Energy & Exploration Partners, LLC as provided in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserve Information promulgated by the Society of Petroleum Engineers. Neither Cawley, Gillespie & Associates, Inc. nor any of its employees has any interest in the subject properties. Neither the employment to make this study nor the compensation is contingent on the results of our work or the future performance of the subject properties. Cawley, Gillespie and Associates, Inc. is a Texas registered engineering firm, F-693, of professional engineers and geologists serving the oil and gas industry for over fifty years.

This report was prepared for the use of Energy & Exploration Partners, LLC. This letter should not be used, circulated or quoted for any other purpose without your express written consent and that of Cawley, Gillespie & Associates, Inc. or except as required by law. Our work papers and related data are available for inspection and review by authorized, interested parties.

 

Respectively Submitted,

 

CAWLEY, GILLESPIE & ASSOCIATES, INC.

Texas Registered Engineering Firm F-693

/s/ Kenneth J. Mueller
Kenneth J. Mueller, PE 86132
Vice President