PART I
When used in
this Annual Report, the terms Heckmann, the Company, we, our, and us refer to Heckmann Corporation and its consolidated subsidiaries, unless otherwise specified.
Overview
Heckmann
Corporation is an environmental solutions company. The Company is one of the largest companies in the United States dedicated to providing comprehensive and full-cycle environmental solutions to our customers in energy and industrial end-markets.
The Company focuses on the delivery, collection, treatment, recycling, and disposal of restricted solids, water, waste water, used motor oil, spent antifreeze, waste fluids and hydrocarbons. Heckmann continues to expand its suite of environmentally
compliant and sustainable solutions to customers that demand environmental compliance and accountability from their service providers.
The following chart describes our strategic focus on providing comprehensive environmental solutions to our customers in industrial and energy end-markets, and the assets we currently possess that allow
us to execute on our strategy:
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Delivery
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Collection
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Treatment
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Recycling
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Disposal
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Solutions
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Fresh water to drilling sites for hydraulic fracturing
Drilling fluids
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E&P liquid waste from fracking
E&P liquid waste from ongoing production
E&P solid waste
Used oil filters
Anti-freeze
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Used motor oil (UMO) into Reprocessed Fuel Oil (RFO)
Oily waste water
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Used oil filters
Anti-freeze
E&P flowback water
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Liquid waste
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Assets
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Over 1,200 trucks
Approximately 4,200 frac tanks and 1,900 upright and other tanks
Over 200 rail cars
50 miles of freshwater delivery pipeline
50 miles of produced water collection pipeline
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Appalachian Water Services, LLC (AWS) plant
a wastewater treatment recycling facility specifically designed to treat and recycle water involved in the hydraulic fracturing process in the Marcellus Shale area
34 Thermo Fluids, Inc. (TFI) treatment facilities process UMO into
RFO
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46 liquid waste disposal wells
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Since the closing of the Thermo Fluids Inc. (TFI) acquisition on April 10, 2012, we have
operated through two business segments: our Fluids Management Division (formerly Heckmann Water Resources or HWR); and our Recycling Division (formerly Heckmann Environmental Services or HES), which includes TFI. Fluids Management addresses the
pervasive demand for diverse water solutions required for the production of oil and gas in an integrated and efficient manner through various service and product offerings. Fluid Managements services include water delivery and disposal,
trucking, fluids handling, treatment, permanent pipeline facilities, water infrastructure services and equipment rental services for oil and gas exploration and production companies. Fluids Management also transports fresh water for drilling and
completion activities and provides services for water pit excavations, site preparation and remediation.
Fluids Management
operates in the United States in the Haynesville, Eagle Ford, Marcellus/Utica, Tuscaloosa Marine, Barnett, Mississipian Lime and Permian Basin Shale areas and since the completion of the merger with Badlands Power Fuels, LLC (Power
Fuels) on November 30, 2012 with and into a wholly-owned subsidiary, the Bakken Shale area. Fluids Management serves customers seeking fresh water acquisition, temporary water transmission and storage, transportation, treatment or
disposal of fresh water and complex water flows, such as flowback and produced brine water, in connection with shale oil and gas hydraulic fracturing drilling, or hydrofracturing, operations. Fluids Management also includes our majority
investment in Appalachian Water Services, LLC (AWS), which owns and operates a state-of-the-art wastewater treatment facility specifically designed to treat and recycle water involved in the hydraulic fracturing process in the Marcellus
Shale area.
Recycling provides route-based environmental services and waste recycling solutions that focus on the collection
and recycling of used motor oil (UMO) and is the largest seller of reprocessed fuel oil (RFO) from recovered UMO in the Western United States. Historically, Recycling has supplied a large percentage of its RFO for use in the
production of asphalt, and consequently experiences some seasonality in its business.
During 2013, the Company intends to
commence an internal reorganization with the intention of managing the Companys operations by end-markets served, which currently include energy and industrial markets. The Company expects
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that its business operations will consist of three operating segments: one of which (Industrial Recycling Solutions) will focus primarily on industrial end-markets, and the other two
of which (Oil Shale Solutions and Gas Shale Solutions, and collectively Shale Segments) will focus on the shale energy end-markets. In each of these proposed operating segments, our focus will be dedicated to
achieving our strategic objective of providing comprehensive environmental solutions to our customers centering on the delivery, collection, treatment, recycling, and disposal of restricted products.
In the operating segments focused on energy end-markets, we provide environmental solutions for exploration and production
(E&P) companies focused on the extraction of oil and natural gas resources from shale or unconventional basins. Pro forma for the operations of Power Fuels, which we merged with in the fourth quarter of 2012,
approximately 70% of our shale-related revenues are derived from areas where oil or liquids drive activity, with the remaining 30% from natural-gas focused areas. We currently operate in the following shale basins: Bakken, Eagle Ford, Marcellus,
Utica, Haynesville, Barnett, Tuscaloosa Marine, and Mississippian Lime Shale areas and the Permian Basin shale area.
We also
provide environmental solutions for industrial end-markets, including the collection, treatment, and recycling of waste products including used motor oil, or UMO, wastewater, spent antifreeze, used oil filters, and parts washers. We
collected approximately 53 million gallons of used oil in 2012, making us the largest used oil collection and recycling company in the Western U.S. We also are a leading seller of reprocessed fuel oil (RFO), and provide other
complementary collection, treatment, recycling, and disposal services to industrial customers.
During 2013, we expect our
operating segments to consist of:
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Oil Shale Solutions
: includes our operations in the Bakken Shale area of North Dakota, which includes the operations of Power Fuels, which we
merged with in the fourth quarter of 2012, the Utica, the Eagle Ford, the Tuscaloosa Marine, the Mississippian Lime, and the Permian Basin shale areas;
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Gas Shale Solutions
: includes our operations in the North & South Marcellus Shale area, our operations in the Haynesville Shale area,
including our pipeline delivery and collection assets, and our operations in the Barnett Shale area; and
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Industrial Recycling Solutions
: includes the operations we acquired in the second quarter of 2012 from TFI, and currently includes operations in
19 states.
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Competitive Strengths
We believe our business possesses the following competitive strengths which position us to serve our customers and grow our revenue and cash flow:
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Leading Transportation & Logistics Network to Control Delivery and Collection
. We have a transportation and logistics network
consisting of over 1,200 trucks, 200 rail cars, 50 miles of freshwater delivery pipeline and 50 miles of produced water collection pipeline. The products we move with our network include fresh water, drilling fluids, liquid/solid waste, used oil
filters, spent anti-freeze, used motor oil, and oily waste water, and allow us to ensure our customers that their restricted environmental products are being controlled in a safe and responsible manner as they make their way to either treatment,
recycling, or disposal options.
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Customer Base That Is Highly Focused on Environmental Responsibility and Compliance.
Our customers are extremely concerned with
conducting their operations with high levels of environmental responsibility and compliance, and place a premium on a national environmental solutions provider who is focused exclusively on the safe and responsible delivery, collection, treatment,
recycling, and disposal of their restricted environmental products. In our energy end-markets there is a significant amount of scrutiny on the environmental impact of shale oil and gas production. We believe major integrated and international energy
companies are likely to play an increasing role in the development of unconventional shale areas, and have shale operations in multiple basins. As a result, we believe there is significant demand for a focused environmental solutions company, such
as Heckmann, that is not distracted by other service offerings, including downhole services. In our Industrial Recycling Solutions division, the collection of UMO is subject to stringent regulatory requirements and facility permitting processes
that, depending on the type of facility, can take several years to complete. We provide customers in both segments the ability to effectively outsource many of the regulatory issues surrounding their business and allow them the ability to focus on
their core competencies.
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National Operating Footprint to Serve Customers that Operate in Multiple Shale Basins
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We are one of the few companies solely
focused on environmental solutions that has a national operating capability with a strong presence in the majority of the unconventional shale basins. An increasing number of customers operating in shale basins have a
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presence in multiple basins, including a growing number of super majors, majors, and large independent companies. As a result, we believe we have a competitive advantage relative to many smaller
competitors because we are able to have a national-level dialogue with these customers on environmental solutions and provide a consistent and comprehensive solutions-based approach to their environmental needs across their operations in various
basins.
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Rapidly Growing Market Segment with No Pure Environmental Solutions Competitor.
We believe that our energy end-markets present our
Company with a highly unique growth opportunity. Many outside analysts are predicting significant growth in U.S. domestic oil and natural gas production, largely as a result of advances in drilling and completion techniques in the unconventional
shale basins that we operate in. These new techniques require significant environmental solutions to deal with restricted waste products, and our customers are extremely focused on the responsible and safe handling of these products. As such, we
believe that our strategy of providing a comprehensive environmental solution, from collection through disposal, provides us a strong competitive advantage. Many of our competitors offer only a component of this value chain, and offer environmental
services as a small component of their overall business services. We believe our singular focus on surface-related environmental solutions allows us to provide our customers with a national, consistent, professional and highly focused value
proposition that is highly differentiated from many of our competitors.
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Cash Flow Visibility with a Strong Customer Base
. We have a diversified business model that provides us with cash flow visibility. A
portion of our revenue is derived from environmental product flows that comes from wells that have already been drilled, and we believe their ongoing production is a function of marginal costs of production. Our Industrial Recycling Solutions
division further diversifies our cash flow profile and end-market concentration. We have a strong customer base that includes a majority of the largest global super major and major energy companies, as well as a number of large industrial customers.
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Operational, Environmental and Regulatory Expertise
. We believe our management team and employees have developed significant expertise
regarding the issues surrounding environmental waste products, and can efficiently and safely provide services to our customers to manage this aspect of their business. We can use this ability to provide excellent service and identify new solutions
for our customers. We expect demand for our services to increase as regulations increase the financial and operational burdens on our customers.
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Strategy
Our strategy is to continue to expand our solutions-based relationships with our
customers and provide a comprehensive, full-cycle environmental solution including delivery, collection, treatment, recycling, and disposal of environmental waste products. The principal elements of our business strategy are to:
Leverage Our Transportation Network to Expand Treatment, Recycling, and Disposal Solutions
. We intend to leverage our advanced
transportation and logistics system to continue to expand our treatment, recycling, and disposal environmental solutions. We believe we have a leading network providing for delivery and collection solutions, and as the market in the unconventional
shales evolves, customers will put an increasing focus on treatment and recycling solutions, particularly around solid waste products. Our current transportation and logistics footprint gives us an opportunity to continue to expand our customer
touch-points and provide end-to-end solutions, from delivery through disposal.
Pursue Growth and Consolidation Opportunities in Our
Industrial Recycling Solutions Division
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We believe there are a number of avenues to grow our Industrial Recycling Solutions division, including through regional acquisition opportunities to grow our share in existing markets and
expand our operations in geographic adjacencies. The UMO market is highly fragmented, and we believe we are one of only three multi-regional players and the largest UMO collector in the western U.S. The majority of competition in our current market
areas comes from smaller local or regional players, and as such we believe we can pursue acquisition opportunities to continue to grow this division.
Focus on Consistent and Analytical Operational Improvement
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We intend to aggressively integrate and implement best practices across our business. Our customers require high levels of
regulatory and environmental compliance, which we emphasize through employee training, maintenance of our asset base and ongoing analysis of our operating performance. In addition, we believe that there are best-practices in certain of our current
shale geographies that can be expanded to other areas of operations to drive revenues and cash flow. We also intend to aggressively pursue the implementation of new accounting, invoicing, and fleet management systems to reduce costs and paperwork,
improve data collection and increase operating efficiency.
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Maintain a Stable and Balanced Capital Structure with Significant Financial Flexibility to Pursue Growth Opportunities.
We intend
to maintain a capital structure that provides us with the flexibility to continue to grow our business. We currently have a $325 million revolving line of credit with $147 million drawn, providing us with over $177 million of liquidity on our bank
line, plus an additional $16.2 million of cash as of December 31, 2012.
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Industry Overview
Energy End-Markets
Over the past several years, E&P companies have focused on utilizing the vast resource potential available across many of North
Americas unconventional resource areas through the application of horizontal drilling and completion technologies, including multi-stage hydraulic fracturing technologies. We believe long-term capital for the continued development in new and
existing basins will be provided in part by the large, well-capitalized domestic and international oil and natural gas companies that have made and continue to make significant capital commitments through joint ventures and direct investments in
North Americas unconventional basins. We believe these companies are highly focused on environmental responsibility, compliance, and regulatory issues and prefer to work with large, highly qualified national solutions providers.
Advances in drilling technology and the development of unconventional North American hydrocarbon plays allow previously inaccessible or
non-economical formations in the earths crust to be exploited by utilizing high pressure methods from millions of gallons of freshwater (or the process known as hydraulic fracturing, or fracking) combined with proppant fluids (containing sand
grains or microscopic ceramic beads) to crack open new perforation depths and fissures to extract large quantities of natural gas, oil, and other hydrocarbon condensates. Significant amounts of water are required to be delivered to the well for
hydraulic fracturing operations, and subsequently, complex water flows, in the forms of flowback and produced water, represent a waste stream from these methods of hydrocarbon exploration and production. Produced water volumes, which represent water
from the formation produced alongside hydrocarbons over the life of the well, are generally driven by marginal costs of production and frequently create a multi-year demand for our services once the well has been drilled. In addition to the liquid
product stream involved in the hydraulic fracturing process, there are also significant environmental solid waste streams that are generated during the drilling and completion of a well. During the drilling process, a combination of the cut rock, or
cuttings, mixed with the liquid used to drill the well, is returned to the surface and must be handled in accordance with environmental and other regulations. Historically, much of this solid waste byproduct was buried at the wellsite.
We believe that customers will increasingly be focused on the treatment and offsite disposal of the solid waste byproduct as regulations increase the financial and operational burdens.
We primarily operate in the Bakken, Eagle Ford, Marcellus, Utica, Haynesville, Mississippian Lime, Tuscaloosa Marine and Barnett Shale
areas.
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The Bakken and underlying Three Forks formations are the two primary reservoirs currently being exploited in the Williston Basin, which covers most of
western North Dakota, eastern Montana, northwest South Dakota and southern Saskatchewan. The Bakken formation occupies about 200,000 square miles of the subsurface of the Williston Basin in Montana, North Dakota and Saskatchewan, and the Three Forks
formation lies directly below North Dakotas portion of the Bakken formation, where oil-producing rock is located between layers of shale about two miles underground. According to the U.S. Energy Information Administration, or the
EIA, June 2012 Annual Energy Outlook, as of January 1, 2010, the Bakken Shale area had more than 5.37 billion barrels of technically recoverable oil reserves. The Bakken Shale area is now one of the most actively drilled
unconventional resource plays in North America, with North Dakota daily crude oil production reaching over 730,000 barrels per day, currently ranking second among U.S. states in daily average crude oil production.
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The Haynesville Shale area is located across northwest Louisiana and east Texas, and extends into Arkansas. The Haynesville Shale area is the second
largest natural gas-producing basin in North America, with an estimated 65.9 Tcf of technically recoverable gas and production of nearly 6.2 Bcf/d as of November 2012, or more than 5% of U.S. total natural gas production. The decline in natural gas
prices has led to a decrease in new well drilling and the number of rigs located in the Haynesville Shale area, and we have responded by transferring a portion of our mobile assets to more oil- and liquids-rich shale plays.
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The Eagle Ford Shale area is a gas and oil play located across southern Texas. The play contains a high liquid component, which has led to the
definition of three areas: oil, condensate and dry gas. The Eagle Ford Shale is estimated to have approximately 50.2 Tcf of technically recoverable gas and 2.5 Bbbl of technically recoverable oil, according to the EIA.
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The Marcellus Shale area is located in the Appalachian Basin in the Northeastern United States (primarily in Pennsylvania, West Virginia, New York and
Ohio). The Marcellus Shale is the largest natural gas field in North America with approximately 140.6 Tcf of technically recoverable gas, according to the EIA.
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Adjacent to the Marcellus Shale is the emerging Utica Shale, located primarily in southwestern Pennsylvania and eastern Ohio. Still in the early stages
of development, the Utica Shale play has three identified areas: oil, condensate and dry gas. According to the EIA, the Utica Shale has an estimated technically recoverable reserve potential of between 1.3 and 5.5 Bbbl of oil and 3.8 to 15.7 Tcf of
natural gas.
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The Barnett Shale is located within the Fort Worth and Permian Basins in Texas and is estimated to have approximately 43.4 Tcf of technically
recoverable gas, according to the EIA. The Barnett Shale is the third largest natural gas-producing basin in the United States, producing approximately 4.6 Bcf/d as of November 2012, or approximately 4% of total U.S. natural gas production.
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The Mississippian Lime play is an old producing field with over 17,000 vertical wells drilled since the 1930s, but has recently become an emerging
horizontal shale play in Northern Oklahoma and Southern Kansas that is marked by significant amounts of produced water. According to the Kansas Department of Commerce, the Mississippian Lime was producing approximately 155 mbbl/d of oil and 1.1bcf/d
as of October 2012. We are transferring to and adding additional operating assets in the Mississippian Lime.
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The Tuscaloosa Marine Shale area, located in southern Louisiana, is an emerging oil- and liquids-rich shale play.
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Industrial End-Markets
The Companys industrial end-market is comprised of companies that provide routine collection of used oil (and other related wastes) from a broad range of commercial and industrial businesses. As a
result of environmental regulations that prohibit the disposal of UMO into sewers or landfills, generators of UMO must arrange to have their waste picked up periodically in order to avoid their storage tanks getting full. Following collection, the
UMO is reprocessed into RFO, a commercial-grade fuel product, and sold as (i) an alternative to traditional energy (i.e., natural gas, virgin oil and diesel fuel) or (ii) feedstock for re-refining into base lube oil.
An estimated 1.4 billion gallons of UMO are generated annually in the U.S., of which 1.0 billion gallons are collected. Approximately
two-thirds of the overall market volume is generated by automotive service providers as a result of performing oil changes on passenger cars and trucks with the remaining one-third coming from industrial plants.
Once collected, the UMO is reprocessed into RFO and sold into the following markets:
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Energy-Intensive Industries
approximately 70% of RFO produced in the U.S. is sold to asphalt plants, pulp and paper mills, and other
energy-intensive industries in which it can be burned as a fuel source. As an alternative to diesel fuel and natural gas, RFO has historically sold at a substantial discount to virgin oil prices. On a per-gallon basis, the discount of RFO to diesel
has typically ranged between 30% and 50% of the cost of diesel fuel. In addition, during periods of increasing energy prices, this discount has widened as diesel price increases typically outpace RFO. Conversely, declining energy price environments
have generally seen diesel prices decline faster than RFO.
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Re-refining
approximately 30% of RFO produced in the U.S. is sold to the re-refining industry, where it is processed and converted into a
base lubricating oil that can typically be sold for higher prices than used oil fuels. As a result of attractive return dynamics and increased awareness of green energy recycling trends, some experts forecast industry capacity to
increase from 290 million gallons per year currently to 540 million gallons per year over the next several years as announced re-refining projects come online.
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Operations
In 2012, we completed two major expansions of our business. On
November 30, 2012, we consummated the merger of Power Fuels, an environmental services company with extensive operations in the Bakken Shale area. On April 10, 2012, we established our Recycling Division with the acquisition of TFI which
provides route-based environmental services and waste recycling solutions, including the collection and reprocessing of UMO.
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Energy End-Market Operations
We address the pervasive demand for diverse environmental solutions required for unconventional oil and gas production. We focus on
providing one-stop total environmental solutions centering around the delivery, collection, treatment, recycling, and disposal of liquid and solid environmental products used in oil and gas drilling and production activities.
Our assets focused on serving energy end-markets include a 50-mile underground pipeline network in the Haynesville Shale area for the
efficient delivery of fresh water and removal of produced water. We also have approximately 200 miles of portable poly and aluminum pipe and associated pumps and other equipment that are used above ground for pumping and transporting water, which
can generally be moved to meet customer demand and market conditions. With the addition of the Power Fuels assets acquired in the merger, we now own and operate a fleet of more than 1,200 trucks for delivery and collection, including 104
low-emission LNG trucks, and approximately 4,200 frac tanks, 1,900 upright and other tanks, and we own or lease 46 operating salt water disposal or underground injection wells in the Bakken, Marcellus/Utica, Haynesville, Eagle Ford, and Tuscaloosa
Shale areas. We continually assess our equipment mix and, as needs and demand require, will invest in additional equipment or improvements to our existing equipment.
Industrial End-Market Operations
Our Recycling Division (formerly
referred to as Heckmann Environmental Services or HES) was initiated with our acquisition of TFIs operations and assets in April 2012. The Recycling Division provides route-based environmental services and waste recycling solutions, offering
customers a reliable, high-quality and environmentally responsible solution through our one-stop shop of collection and recycling services for waste products including UMO, oily water, spent antifreeze, used oil filters and parts
washers. Our Recycling Division collects UMO and reprocesses it to be sold in the form of RFO to (i) re-refiners as a critical feedstock for the production of base lubricants and (ii) industrial customers as a lower cost, higher British
Thermal Units (BTU) alternative to diesel fuel. We collected more than approximately 53 million gallons of used oil in 2012, making us the largest used oil collection and recycling company in the western U.S.
Our assets focused on serving industrial end-markets include 34 processing facilities, 385 tanker trucks, vacuum trucks and trailers, and
over 200 railcars as of December 31, 2012. With a presence in 19 states stretching from Washington to Texas, we provide a suite of essential services to more than 20,000 commercial and industrial customers that collectively generate high
volumes of regulated non-hazardous waste on a daily basis.
Our UMO volume is sourced from participants within the automotive
service industry (e.g., quick lube shops, auto dealerships, retail automotive service providers, etc.) and a diverse array of commercial and industrial operations across the trucking, railroad, manufacturing and mining industries. We have
established relationships with more than 250 RFO customers located throughout the United States, typically consisting of re-refiners and energy-intensive industries that require the use of a boiler or furnace, such as the asphalt, pulp, paper and
bunker fuel markets.
Customers
In our energy end-markets, our customers include major United States and international oil and gas companies, foreign national oil and gas companies and independent oil and natural gas production
companies that are active in our core areas of operations. In Recycling, we have established relationships with more than 20,000 mostly small-to medium-sized UMO-generating facilities and more than 250 RFO customers located throughout the western
United States. In the year ended December 31, 2012, Chesapeake Energy Corp., Royal Dutch Shell plc (Shell) and Omega Holdings Company, LLC represented 15%, 15% and 9%, respectively, of our total consolidated revenues. In Recycling,
Omega Holdings Company, LLC accounted for approximately 34% of our sales of RFO for the year ended December 31, 2012, while no single generator accounted for more than 5% of UMO volume in 2012. In our energy end-markets segments, in addition to
Chesapeake Energy Corp. and Shell, we expect Hess Corporation and Whiting Oil & Gas Corporation, which accounted for approximately 33% and 25%, respectively, of the 2012 revenues of Power Fuels, which we merged with in the fourth quarter of
2012, to become increasingly important to our business.
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Competitors
In our energy end-markets segments, there are a limited number of competitors who approach the market similarly to Heckmann. Some competitors are focused primarily on treatment, recycling, and disposal
operations, preferring to avoid the logistical components of delivery and collection, and include Tervita Corporation, R360 Environmental Solutions (now part of Waste Connections, Inc.), and Clean Harbors, Inc.. We believe that offering a
comprehensive environmental solution to our customers, which includes certainty of control of environmental products from generation through disposal, is an important value proposition and will only increase in importance over time. We believe the
logistical network we have built to provide delivery and collection is a significant competitive advantage relative to these competitors.
Other competitors offer certain environmental services as ancillary offerings to their core businesses, which are focused largely on the downhole aspects of oil and natural gas operations. Unlike us, many
of these competitors also conduct hydraulic fracturing operations, examples of which would include Schlumberger Limited, Baker-Hughes, Inc., Key Energy Services, Inc. and Basic Energy Services, Inc. However, none of these companies focus entirely on
the surface environmental aspects of unconventional oil and natural gas operations, a key aspect of our strategy. Other competitors focus primarily or exclusively on the fluids handling aspects of hydraulic fracturing and include numerous small,
regional enterprises.
The UMO collection and recycling industry is highly fragmented, with a significant number of companies
competing for the environmental services needs of commercial and industrial customers nationwide. These competitors include national companies such as Safety-Kleen (now part of Clean Harbors) and FCC Environmental, LLC, regional players such as
Midstate Environmental Services, LP and Emerald Oil, Inc., and various local collectors. Companies operating in the industry typically utilize one of the following business models:
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Collect UMO only
: these tend to be smaller and lack the access to capital required to build out full treatment facilities.
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Collect UMO and produce RFO
: most small- to mid-sized companies in the industry collect UMO and treat it to produce RFO and tend to operate on a
regional basis. Currently, we operate according to this model.
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Collect UMO & re-refine
: Select larger companies in the industry collect UMO themselves or purchase UMO from third parties for
re-refining. These companies utilize sophisticated, capital intensive processes for re-refining used oil into the equivalent of other virgin oil products. The largest player in the UMO market, Clean Harbors (which acquired Safety-Kleen), operates
under this model.
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As a result, the markets in which we operate are highly competitive and certain of our
competitors in both our energy end-markets segments and our Industrial Recycling Solutions segment have longer industry tenure and greater resources than us. Competition is influenced by such factors as price, capacity, availability of work crews
and equipment, HS&E programs, legal compliance, technology, reputation and experience. We believe we can compete effectively in the environmental solutions sector as a result of our extensive industry experience, depth and breadth of transport,
treatment and disposal assets, focus on HS&E and commitment to customer service.
Health, Safety & Environment
We are committed to excellence in HS&E in our operations, which we believe is a critical characteristic for our business.
Our customers in the unconventional shale basins, including many of the large integrated and international oil and gas companies, require us, as a service provider, to meet high standards on HS&E matters. As a result, we believe that being a
large environmental solutions company with a national presence and a dedicated focus on environmental solutions with a track record on HS&E in our operations and in the services we provide our customers is a competitive advantage relative to
smaller regional companies as well as companies that provide certain environmental services as an ancillary offering.
Seasonality
Our business segments are impacted by seasonal factors. Generally, our business is negatively impacted during the winter
months due to inclement weather, fewer daylight hours and holidays. During periods of heavy snow, ice or rain, we may not be able to move our trucks and equipment between locations, thereby reducing our ability to provide services and generate
revenues. In addition, these conditions may impact our customers operations, and, as our customers drilling activities are curtailed, our services may also be reduced. During the fourth quarter, we historically have experienced slowdown
during the Thanksgiving and Christmas holiday seasons and demand sometimes slows during this period as our customers exhaust their annual capital spending budgets.
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Historically, Recycling has supplied a large percentage of its RFO for use in the production
of asphalt, and consequently experiences some seasonality in its business. Demand for asphalt and asphalt products is generally higher during the summer months due to increases in highway traffic and road construction work.
Intellectual Property
We operate under numerous trade names and own several trademarks, the most important of which are Heckmann, HWR,
and Heckmann Water Resources. We also have access, through certain exclusive and business relationships, to various water treatment technologies which, based on our experience, we utilize to create unique, cost-effective and proprietary
total water treatment solutions for our customers.
Operating Risks
Our operations are subject to hazards inherent in our industry, including accidents and fires that could cause personal injury or loss of
life, damage to or destruction of property, equipment and the environment, and suspension of operations. Because our business involves the transportation of materials, we may also experience traffic accidents or pipeline breaks which may result in
spills, property damage and personal injury. We have implemented a comprehensive HS&E program designed to minimize accidents in the workplace, enhance our safety programs, maintain environmental compliance and improve the efficiency of our
operations.
Governmental Regulation, including Environmental Regulation and Climate Change
Our operations are subject to stringent United States federal, state and local laws and regulations regulating the discharge of materials
into the environment or otherwise relating to health and safety or the protection of the environment. Additional laws and regulations, or changes in the interpretations of existing laws and regulations, that affect our business and operations may be
adopted, which may in turn impact our financial condition. The following is a summary of the more significant existing health, safety and environmental laws and regulations to which our operations are subject.
Hazardous Substances and Waste
. The United States Comprehensive Environmental Response, Compensation, and Liability Act, as
amended, referred to as CERCLA or the Superfund law, and comparable state laws, impose liability without regard to fault or the legality of the original conduct on certain defined persons, including current and prior owners
or operators of a site where a release of hazardous substances 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 liable for the
costs of cleaning up the hazardous substances, for damages to natural resources and for the costs of certain health studies.
In the course of our operations, we occasionally generate materials that are considered hazardous substances and, as a
result, may incur CERCLA liability for cleanup costs. Also, claims may be filed for personal injury and property damage allegedly caused by the release of hazardous substances or other pollutants. We also generate solid wastes that are subject to
the requirements of the United States Resource Conservation and Recovery Act, as amended, or RCRA, and comparable state statutes. In particular, RCRA standards require our Recycling Division to track all shipments of UMO and RFO destined
for market and verification that the materials marketed by us meet the definition of on-specification used oil, which results in less stringent pollution controls, if any. If our products are deemed to be off-specification,
potentially new emission standards could be imposed on our customers facilities that burn on-specification used oil (e.g. asphalt plants).
Although we use operating and disposal practices that are standard in the industry, hydrocarbons or other wastes may have been released at properties owned or leased by us now or in the past, or at other
locations where these hydrocarbons and wastes were taken for treatment or disposal. Under CERCLA, RCRA and analogous state laws, we could be required to clean up contaminated property (including contaminated groundwater), or to perform remedial
activities to prevent future contamination.
Air Emissions.
The Clean Air Act, as amended, or CAA, and
similar state laws and regulations restrict the emission of air pollutants and also impose various monitoring and reporting requirements. These laws and regulations may require us to obtain approvals or permits for construction, modification or
operation of certain projects or facilities and may require use of emission controls.
Global Warming and Climate Change.
While we do not believe our operations raise climate change issues different from those generally raised by the commercial use of fossil fuels, legislation or regulatory programs that restrict greenhouse gas emissions in areas where we conduct
business or that would require reducing emissions from our truck fleet could increase our costs.
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Water Discharges.
We operate facilities that are subject to requirements of the
United States Clean Water Act, as amended, or CWA, and analogous state laws for regulating discharges of pollutants into the waters of the United States and regulating quality standards for surface waters. Among other things these laws
impose restrictions and controls on the discharge of pollutants, including into navigable waters as well as protecting drinking water sources. Spill prevention, control and counter-measure requirements under the CWA require implementation of
measures to help prevent the contamination of navigable waters in the event of a hydrocarbon spill. Other requirements for the prevention of spills are established under the United States Oil Pollution Act of 1990, as amended, or OPA,
which amended the CWA and applies to owners and operators of vessels, including barges, offshore platforms and certain onshore facilities. Under OPA, regulated parties are strictly liable for oil spills and must establish and maintain evidence of
financial responsibility sufficient to cover liabilities related to an oil spill for which such parties could be statutorily responsible.
Oil Pollution Act.
The United States Oil Pollution Act, as amended, or OPA, governs any facility that has the capacity to store more than 1,320 gallons of oil and/or petroleum products
and has the potential to discharge to a navigable water of the United States. All our Recycling facilities are subject to this regulation, which requires that each facility develop and maintain a Spill Prevention Control and
Countermeasures Plan, or SPCC. The SPCC requires certain planning and training to minimize the potential for oil and/or other petroleum products to be released into a navigable waterway.
National Pollutant Discharge Elimination System.
Our Recycling Divisions storm water discharges and waste water discharges
are regulated by the National Pollutant Discharge Elimination System, or NPDES, permit program. Many of Recyclings facilities are required to manage their storm water runoff according to a Multi Sector General Permit
issued by the EPA or by a particular state, if the state has been delegated authority to administer the program. Under NPDES, our regulated facilities must maintain a Storm Water Pollution Prevention Plan that identifies certain best management
practices to minimize the off-site impact of any pollutants that may be carried off-site by precipitation. Very few of Recyclings locations require specific waste water discharge permits from industrial processes.
State Environmental Regulations.
Our operations involve the storage, handling, transport and disposal of bulk waste materials,
some of which contain oil, contaminants and other regulated substances. Various environmental laws and regulations require prevention, and where necessary, cleanup of spills and leaks of such materials and some of our operations must obtain permits
that limit the discharge of materials. Failure to comply with such environmental requirements or permits may result in fines and penalties, remediation orders and revocation of permits. In Texas, we are subject to rules and regulations promulgated
by the Texas Railroad Commission and the Texas Commission on Environmental Quality, including those designed to protect the environment and monitor compliance with water quality. In Louisiana, we are subject to rules and regulations promulgated by
the Louisiana Department of Environmental Quality and the Louisiana Department of Natural Resources as to environmental and water quality issues, and the Louisiana Public Service Commission as to allocation of intrastate routes and territories for
waste water transportation. In Pennsylvania, we are subject to the rules and regulations of the Pennsylvania Department of Environmental Protection and the Pennsylvania Public Service Commission. In Ohio, we are subject to the rules and regulations
of the Ohio Department of Natural Resources and the Ohio Environmental Protection Agency. In North Dakota, are subject to the rules and regulations of the North Dakota Department of Health, the North Dakota Industrial Commission, Oil and Gas
Division, and the North Dakota State Water Commission. In Montana, we are subject to the rules and regulations of the Montana Department of Environmental Quality and the Montana Board of Oil and Gas.
In addition, Recyclings operations involve the storage, handling, transport and disposal of bulk waste materials, some of which
contain oil, contaminants and other regulated substances. Various state environmental laws and regulations require prevention, and where necessary, cleanup of spills and leaks of such materials and some of our operations must obtain permits that
limit the discharge of materials. Failure to comply with such environmental requirements or permits may result in fines and penalties, remediation orders and revocation of permits. For example, in California, Recycling is subject to the Department
of Toxic Substances Control, or DTSC, controls on the shipment and management of used oil. Recycling has worked with the California DTSC to develop a testing and reporting agreement with the to assist transporters of used motor oil to
meet the states standard.
Occupational Safety and Health Act.
We are subject to the requirements of the United
States Occupational Safety and Health Act, as amended, or OSHA, and comparable state laws that regulate the protection of employee health and safety. OSHAs hazard communication standard requires that information about hazardous
materials used or produced in our operations be maintained and provided to employees, state and local government authorities and citizens.
Saltwater Disposal Wells.
We operate salt water disposal wells that are subject to the CWA, the Safe Drinking Water Act, or SWDA, and state and local laws and regulations, including
those established by the Underground Injection Control Program of the United States Environmental Protection Agency, or EPA, which establishes the minimum program requirements including for permitting, testing, monitoring, record keeping
and reporting of injection well activities. All of our salt water disposal wells are located in Ohio, Mississippi, Texas, North Dakota and Montana. Regulations in Texas, Louisiana and Ohio, North Dakota and Montana require us to
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obtain a permit to operate each of our salt water disposal wells in those states. These regulatory agencies have the general authority to suspend or modify one or more of these permits if
continued operation of one of our underground injection wells is likely to result in pollution of freshwater, substantial violation of permit conditions or applicable rules, or leaks to the environment. Any leakage from the subsurface portions of
the injection wells could cause degradation of fresh groundwater resources, potentially resulting in cancellation of operations of a well, issuance of fines and penalties from governmental agencies, incurrence of expenditures for remediation of the
affected resource and imposition of liability by third parties for property damages and personal injuries.
Transportation
regulations.
We conduct interstate motor carrier (trucking) operations that are subject to federal regulation by the Federal Motor Carrier Safety Administration, or FMCSA, a unit within the United States Department of Transportation,
or USDOT. The FMCSA publishes and enforces comprehensive trucking safety regulations, including rules on commercial driver licensing, controlled substance testing, medical and other qualifications for drivers, equipment maintenance, and
drivers hours of service, referred to as HOS. The agency also performs certain functions relating to such matters as motor carrier registration (licensing), insurance, and extension of credit to motor carriers customers.
Another unit within USDOT publishes and enforces regulations regarding the transportation of hazardous materials, or hazmat, but the waste water and other water flows we transport by truck are not normally regulated as hazmat at this
time.
In December 2010, the FMCSA launched a program called Compliance, Safety, Accountability, or CSA, in an
effort to improve commercial truck and bus safety. A component of CSA is the Safety Measurement System, or SMS, which will continuously analyze all safety violations recorded by the federal and state law enforcement personnel to
determine a carriers safety performance. The SMS is intended to allow the FMCSA to identify carriers with safety issues and intervene to address those problems. Although our trucking operations currently hold a Satisfactory safety
rating from FMCSA (the best rating available), the agency has announced a future intention to revise its safety rating system by making greater use of SMS data in lieu of on-site compliance audits of carriers. We cannot predict the effect of such a
revision on our safety rating.
Our intrastate trucking operations are also subject to the state environmental and waste water
transportation regulations discussed under Environmental Regulations above. Federal law also allows states to impose insurance and safety requirements on motor carriers conducting intrastate business within their borders, and to
collect a variety of taxes and fees on an apportioned basis reflecting miles actually operated within that state.
The HOS
regulations establish the maximum number of hours that a commercial truck driver may work. A new FMCSA rule reducing the number of hours a commercial truck driver may work each day became effective in February 2012 and the compliance date of
selected provisions is July 1, 2013. The new rule, which is intended to reduce the risk of fatigue and fatigue-related crashes and harm to driver health in several ways, among other things prohibits a driver from driving if more than eight
hours have passed since the drivers last off-duty or sleeper berth break of at least 30 minutes and limits the use of the restart to once a week, which, on average, will cut the maximum work week from 82 to 70 hours. The effect of reduced
driver hours may raise operating costs for many if not most truck fleets.
In addition, the USDOTs Pipeline and
Hazardous Materials Safety Administration regulates the transportation of materials deemed by to be hazardous while in transport. A small portion of the materials that Recycling transports are subject to these regulations, which require certain
training and communication rules to ensure the safe transport of hazardous materials.
Hydraulic Fracturing
. Although
we do not directly engage in hydraulic fracturing activities, certain of our customers, particularly our Fluids Management customers, perform hydraulic fracturing operations. While we believe that the adoption of new federal and/or state laws or
regulations imposing increased regulatory burdens on hydraulic fracturing could increase demand for our services, it is possible that it could harm our business by making it more difficult to complete, or potentially suspending or prohibiting, crude
oil and natural gas wells in shale formations, increasing our and our customers costs of compliance and adversely affecting the hydraulic fracturing services that we provide for our customers.
Due at least in part to public concerns that have been raised regarding the potential impact of hydraulic fracturing on drinking water,
the EPA has commenced a comprehensive study, at the order of the United States Congress, of the potential environmental and health impacts of hydraulic fracturing activities. A final draft report is expected to be issued by the EPA for public
comment in 2014. On October 15, 2012, a new rule promulgated by the EPA that established new air emission controls for crude oil and natural gas production and natural gas processing operations became effective. The rule includes New Source
Performance Standards, or NSPS, to address emissions of sulfur dioxide and volatile organic compounds, or VOCs, and a separate set of emission standards to address hazardous air pollutants associated with oil and natural gas
production and processing activities. EPAs final rule requires the reduction of VOC emissions from crude oil and natural gas production facilities by mandating the use of green completions for hydraulic fracturing, which requires
the operator to recover rather than vent the gas and natural gas liquids that come to the surface during completion of the fracturing process.
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Legislation, including bills known collectively as the Fracturing Responsibility and
Awareness of Chemicals Act, or FRAC Act, has been introduced before both houses of Congress in the last few sessions to remove the exemption of hydraulic fracturing under the SDWA and to require disclosure to a regulatory agency of chemicals used in
the fracturing process and otherwise restrict hydraulic fracturing. To date, this legislation has not been passed by either house.
Various state, regional and local governments have implemented, or are considering, increased regulatory oversight of hydraulic fracturing through additional permit requirements, operational restrictions,
disclosure requirements, and temporary or permanent bans on hydraulic fracturing in certain environmentally sensitive areas such as certain watersheds. The North Dakota Industrial Commission, Oil and Gas Division recently proposed regulations
requiring owners, operators, and service companies to post the composition of the hydraulic fracturing fluid used during certain hydraulic fracturing stimulations on the FracFocus Chemical Disclosure Registry. The availability of information
regarding the constituents of hydraulic fracturing fluids could potentially make it easier for third parties opposing the hydraulic fracturing process to initiate legal proceedings based on allegations that specific chemicals used in the fracturing
process could adversely affect groundwater. In addition, North Dakota recently proposed regulations prohibiting the discharge of fluids, wastes, and debris other than drill cuttings into open pits.
Employees
As of
December 31, 2012, we had 2,698 full time employees, of whom 342 were executive, managerial, sales, general, administrative, and accounting staff, and 2,356 were truck drivers, service providers and field workers. In addition, as of
December 31, 2012, we contracted with approximately 65 independent contractor truck drivers to supplement our trucking capacity in the Bakken Shale area on an as-needed basis. None of our employees are under collective bargaining agreements. We
believe that we maintain a satisfactory working relationship with our employees and we have not experienced any significant labor disputes.
Additional Information
Information that we file with or furnish to the SEC, including our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current
Reports on Form 8-K, and any amendments to or exhibits included in these reports, are available free of charge on our website at www.heckmanncorp.com soon after such reports are filed with or furnished to the SEC. From time to time, we also post
announcements, updates, events, investor information and presentations on our website in addition to copies of all recent press releases. Our reports, including any exhibits included in such reports, that are filed with or furnished to the SEC are
also available on the SECs website at www.sec.gov. You may also read and copy any materials we file with or furnish to the SEC at the SECs Public Reference Room at 100 F Street, NE, Room 1580, Washington, D.C. 20549; information on the
operation of the Public Reference Room may be obtained by calling the SEC at 1-800-SEC-0330. You may request copies of these documents from the SEC, upon payment of a duplicating fee, by writing to the SEC at its principal office at 100 F Street,
NE, Room 1580, and Washington, D.C. 20549.
Neither the contents of our website nor that maintained by the SEC are
incorporated into or otherwise a part of this filing. Further, references to the URLs for these websites are intended to be inactive textual references only.
You
should carefully consider the risks described below. If any of the risks and uncertainties described in the cautionary factors described below actually occurs, our business, financial condition and results of operations could be materially and
adversely affected. The risks and factors listed below, however, are not exhaustive. Other sections of this Annual Report on 10-K include additional factors that could materially and adversely impact our business, financial condition and results of
operations. Moreover, we operate in a rapidly changing environment. In addition, we are subject to legal and regulatory changes. New factors emerge from time to time and it is not possible to predict the impact of all these factors on our business,
financial condition or results of operations.
Risks Related to Our Company
We may not be able to grow successfully through future acquisitions or successfully manage future growth, and we may not be able to effectively
integrate the businesses we do acquire.
Our business strategy includes growth through the acquisitions of other
businesses in both our Fluids Management and Recycling Divisions. We may not be able to continue to identify attractive acquisition opportunities or successfully acquire those opportunities identified. In order to complete acquisitions, we would
expect to require additional debt and/or equity financing, which could increase our interest expense, leverage and shares outstanding. In addition, we may not be successful in integrating current or future acquisitions into our existing operations,
which may result in unforeseen operational difficulties or diminished financial performance or require a disproportionate amount of our managements attention.
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Even if we are successful in integrating our current or future acquisitions into our
existing operations, we may not derive the benefits, such as operational or administrative synergies or earnings gains`, that we expected from such acquisitions, which may result in the commitment of our capital resources without the expected
returns on such capital. Also, competition for acquisition opportunities may escalate, increasing our cost of making further acquisitions or causing us to refrain from making additional acquisitions.
Additional risks related to our acquisition strategy include, but are not limited to:
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the potential disruption of our existing businesses;
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entering new markets or industries in which we have limited prior experience;
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difficulties integrating and retaining key management, sales, research and development, production and other personnel or diversion of management
attention from ongoing business concerns to integration matters;
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difficulties integrating or expanding information technology systems and other business processes or administrative infrastructures to accommodate the
acquired businesses;
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complexities associated with managing the combined businesses and consolidating multiple physical locations;
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risks associated with integrating financial reporting and internal control systems; and
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whether any necessary additional debt or equity financing will be available on terms acceptable to us, or at all, and the impact of such financing on
our operating performance and earnings per share.
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We may not be able to successfully integrate or realize the
anticipated benefits of our merger with Power Fuels or acquisition of TFI and may not be able to maintain or achieve profitability of the acquired businesses or overall.
Although we have completed a number of smaller acquisitions since mid-2010, Power Fuels and TFI represent, by far, the largest additions
to our business. The integration and consolidation of Power Fuels and TFI has and will continue to require substantial management, financial and logistical and other resources. While we believe that we have sufficient resources to integrate these
businesses successfully, such integration involves a number of significant risks, including diversion of managements attention and resources. Moreover, there can be no assurance as to the extent to which the anticipated benefits of these
transactions will be realized, if at all, or that significant time and cost beyond that anticipated will not be required in connection with the integration of TFI and the continuing operation of the Power Fuels and TFI businesses. If we are unable
to integrate and manage TFI successfully, or to achieve a substantial portion of the anticipated benefits of these acquisitions within the time frames anticipated by management and within budget, it could have a material adverse effect on our
business, financial condition or results of operations.
The merger with Power Fuels and our acquisition of TFI makes evaluating our
operating results difficult given the significance of these transactions, and historical and unaudited pro forma financial information may not give you an accurate indication of how we will perform in the future.
Our acquisition activities, in particular the Power Fuels merger and the acquisition of TFI, may make it more difficult for us to
evaluate and predict our future operating performance. Neither our historical results of operations, nor the separate pre-acquisition financial information of Power Fuels or TFI, give effect to those transactions; accordingly, such historical
financial information does not necessarily reflect what our, Power Fuels or TFIs financial position, operating results and cash flows will be in the future on a consolidated basis following consummation of those transactions. Unaudited
pro forma financial information giving effect to the Power Fuels merger and the TFI acquisition does not represent, and should not be relied upon as reflecting, what our financial position, results of operations or cash flows actually would have
been if the transactions referred to therein had been consummated on the dates or for the periods indicated, or what such results will be for any future date or any future period.
We are vulnerable to the potential difficulties associated with rapid growth.
We believe that our future success depends on our ability to manage the rapid growth that we have experienced, and the continued growth that we expect to experience organically and through acquisitions.
Our growth places additional demands and responsibilities our management to, among other things, maintain existing customers and attract new customers, recruit, retain and effectively manage employees, as well as expand operations and integrate
customer support and financial control systems. The following factors could present difficulties to us: lack of sufficient executive-level personnel, increased administrative burden, long lead times associated with acquiring additional equipment;
availability of suitable acquisition candidates and of additional capacity of trucks, saltwater disposal and underground injection wells, frac tanks, rail cars, processing facilities and pipeline right-of-way; and the ability to provide focused
service attention to our customers in the areas of fracking, oil collection, tank storage, antifreeze collection,
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antifreeze re-manufacturing, industrial waste management and oil and water filtration, among others. In addition, the planned expansion of our LNG truck fleet, and the anticipated cost savings,
are dependent on available infrastructure for LNG refueling, which is currently limited to Haynesville, and the lack of available infrastructure may significantly restrict this planned expansion and the expected benefits of this growth.
Future charges due to possible impairments of assets may have a material adverse effect on our financial condition and results of operations, and
stock price.
A portion of our assets is comprised of goodwill and other intangible assets, which may be subject to
future impairment that would result in financial statement write-offs. Goodwill and other intangible assets represent approximately 51.1% of our total assets as of December 31, 2012, the majority of which relates to the Power Fuels merger and
TFI acquisition. If there is a material change in our business operations or prospects, the value of our intangible assets, or those we may acquire in the future, could decrease significantly.
Accounting Standards Codification 350
(ASC 350 Intangibles Goodwill and Other)
provides specific guidance for testing
goodwill and other non-amortized intangible assets for impairment. The testing of goodwill and other intangible assets for impairment requires us to make significant estimates about our future performance and cash flows, as well as other
assumptions. These estimates can be affected by numerous factors, including changes in the definition of a business segment in which we operate; changes in economic, industry or market conditions; changes in business operations; changes in
competition; or potential changes in the share price of our common stock and market capitalization. Changes in these factors, or changes in actual performance compared with estimates of our future performance, could affect the fair value of goodwill
or other intangible assets, which may result in an impairment charge. Should the value of our goodwill or other intangible assets become impaired, it could have a material adverse effect on our consolidated results of operations and could result in
our incurring net losses in future periods.
On an ongoing basis and at least annually, we evaluate whether the carrying value
of our intangible assets may no longer be recoverable, in which case a charge to earnings may be necessary. We cannot accurately predict the amount or timing of any impairment of assets. Any future determination requiring the write-off of a
significant portion of unamortized intangible assets, although not requiring any additional cash outlay, could have a material adverse effect on our financial condition, results of operations and stock price.
We depend on our senior management.
Our success is largely dependent on the skills, experience and efforts of our people. In particular, the continued services of Mr. Heckmann, our Executive Chairman, and Mr. Johnsrud, our Chief
Executive Officer and Vice Chairman. The loss of the services of Mr. Heckmann or Mr. Johnsrud, or of other members of our senior management could have a negative effect on our business, financial condition and results of operations and
future growth if we were unable to replace them.
Mr. Johnsrud has not previously been the chief executive officer of a
publicly traded company and has no prior experience managing a publicly traded company and complying with federal securities laws, including compliance with disclosure requirements on a timely basis. Our management may be required for a period of
time to divert its attention from operational matters to compliance and reporting requirements, which could harm our business.
We have
had, and may have in the future, material weaknesses in our internal control over financial reporting that could cause investors to lose confidence in our reported financial information and thereby cause a decline in our stock price.
As of December 31, 2012, our management concluded that our internal control over financial reporting was
effective to provide reasonable assurance that the information required to be disclosed in our reports filed with the SEC under the Exchange Act are recorded, processed, summarized and reported within the time periods specified in the SECs
rules and forms, and are accumulated and communicated to our management, including our Chief Executive Officer, as appropriate to allow timely decisions regarding required disclosure. However, we have had in the past and may have in the future
material weaknesses in our internal control over financial reporting.
If we are unable to address any material weaknesses in
our internal control over financial reporting, we may have errors in our financial statements that could result in a restatement of our financial statements, cause us to fail to meet our reporting deadlines, and cause investors to lose confidence in
our reported financial information, leading to a decline in our stock price.
We are engaged in litigation and subject to an SEC inquiry
relating to China Water and Drinks Inc., our former China water bottling business which was disposed of in 2011, and a negative outcome in any of these proceedings could materially adversely affect us.
As described in greater detail in Note 11, Commitments and Contingencies, of the Notes to our 2012 Consolidated Financial Statements
herein, we and certain of our directors and officers are involved in litigation arising from or relating to our acquisition of China Water and Drinks, Inc., or China Water, in October 2008, including a purported class action and a
derivative action. In addition, on June 10, 2011, we received a subpoena from the Denver Regional Office of the SEC seeking information and documents concerning China Water. We are cooperating and intend to continue to cooperate fully with the
SEC with respect to its requests. A negative outcome of the SEC inquiry could result in the SEC imposing fines or penalties on us, or requiring us to satisfy other remedies including modifications to business practices and implementing compliance
programs.
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The litigation and the SEC inquiry are also causing us to incur substantial legal fees and
expenses as well as requiring management time and involvement. The outcome of the litigation and the SEC inquiry are uncertain and, if adversely decided or settled against us or any of our officers or directors, could have a material adverse impact
on our business, financial condition, results of operations and cash flows.
Changes to the fair market or carrying value of our
investments in UGSI could result in a write down.
As of December 31, 2012, we own approximately 7% of
Underground Solutions, Inc., or UGSI, a supplier of water infrastructure pipeline products, which we acquired in 2009 for a total investment of $7.2 million. There is no or limited liquidity in the stock of UGSI. Changes to the fair
market or carrying value of our investments in UGSI could result in a write down of this investment.
Significant capital expenditures
are required to conduct our business.
The development of our business and services, excluding acquisition activities,
requires substantial capital expenditures, particularly in our Fluids Management Division. During the year ended December 31, 2012, we made capital expenditures of approximately $45.6 million, including an expansion of our fleet of trucks and
trailers, additional salt water disposal wells and completion of the construction of a pipeline in the Haynesville Shale area. We fund our capital expenditures through a combination of cash flows from operations and borrowings under our bank credit
facilities and, to the extent those sources are not sufficient, we may fund capital expenditures from the proceeds of debt and equity issuances. Future cash flows from operations are subject to a number of risks and variables, such as the level of
drilling activity and oil and natural gas production of our customers, prices of natural gas and oil, ability to source UMO, demand for RFO, and the other risk factors discussed herein. Our ability to obtain capital from other sources, such as the
capital markets, is dependent upon many of those same factors as well as the orderly functioning of credit and capital markets. To the extent we fail to have adequate funds, we could be required to reduce our capital spending, or pursue other
funding alternatives, which in turn could adversely affect our business and results of operations.
Increases in costs relating to our
large fleet of trucks, including driver compensation or difficulty in attracting and retaining qualified drivers as well as increases in fuel costs, could adversely affect our profitability.
During 2012, we increased the number of truck drivers we employ to approximately 1,630 as of December 31, 2012, compared to
approximately 670 as of December 31, 2011, including approximately 125 additional drivers added through the TFI acquisition and over 600 drivers added through the Power Fuels merger. Maintaining a staff of qualified truck drivers is critical to
the success of our operations. We have in the past experienced difficulty in attracting and retaining sufficient numbers of qualified drivers in some of the markets in which we operate, which difficulty is due in part to our high standards for
retention of drivers. A shortage of qualified drivers and intense competition for drivers from other companies may create difficulties in some regions.
The compensation we offer our drivers is subject to market conditions, and we may find it necessary to increase driver compensation and/or modify the benefits provided to our employees in future
periods.
In Fluids Management, we and other companies in the oil and gas industry suffer from a high turnover rate of
drivers. The high turnover rate requires us to continually recruit a substantial number of drivers in order to operate existing equipment. If we are unable to continue to attract and retain a sufficient number of qualified drivers, we could be
forced to, among other things, adjust our compensation packages, increase the number of our trucks without drivers, or operate with fewer trucks and face difficulty meeting customer demands, any of which could adversely affect our growth and
profitability. Additionally, in anticipation of or in response to geographical and market-related fluctuations in the demand for our services, we strategically relocate our equipment and personnel from one area to another, which results in operating
inefficiencies, increased labor, fuel and other operating costs and could adversely affect our growth and profitability. As a result, our driver and employee training and orientation costs could be negatively impacted.
Increases in oil, natural gas and diesel prices have a significant impact on our operating expenses. The price and supply of oil and fuel
is unpredictable and fluctuates based on events beyond our control, including geopolitical developments, supply and demand for oil, natural gas and LNG, actions by the Organization of Petroleum Exporting Countries, or OPEC, and other oil
and gas producers, war and unrest in oil producing countries, regional production patterns and environmental concerns. Continued increases in/high prices of diesel costs throughout 2012 reduced profit margins in Fluids Management. Fuel prices may
continue to increase significantly in 2013 and beyond, which could adversely affect our operating results, particularly in Fluids Management.
In addition, the supply of critical infrastructure assets, in particular employee housing, in the Bakken Shale area has not kept pace with the rapid growth in the region caused by the boom in the energy
and environmental services industry. As a result, there is a shortage of fixed housing in the region, making it difficult for energy services operators and other businesses to attract quality, long-term personnel. Through an entity he controls, but
which was not included in the Merger, Mr. Johnsrud owns fixed-housing units in the Bakken Shale area. Prior to the merger, Power Fuels employees had priority access to rent the housing owned by this entity, however there is no formal
arrangement with Mr. Johnsrud to ensure that our employees have continued access to rent this housing following the merger. There can be no assurance that there will be sufficient housing available for all of our employees in the Bakken Shale
area, which could adversely affect our ability to provide services and our operating results.
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We depend on certain key customers for a significant portion of our revenues. The loss of any of these
key customers or the loss of any contracted volumes could result in a decline in our business.
We rely on a limited
number of customers for a significant portion of our revenues. Chesapeake Energy Corp., Shell Swepi, LLC, and Omega Holdings Company, LLC represented 15%, 14% and 9% of our total consolidated revenues for the year ended December 31, 2012,
respectively. Additionally, Omega Holdings Company, LLC accounted for approximately 34% of our sales of RFO for the year ended December 31, 2012, and in Fluids Management, Chesapeake Energy Corp., Shell Swepi, LLC, and Chevron Corp. accounted
for approximately 21%, 20% and 11%, respectively, of Fluids Management revenues. The loss of all, or even a portion of, the revenues from these customers, as a result of competition, market conditions or otherwise, could have a material adverse
effect on our business, results of operations, financial condition, and cash flows. For example, our 2012 results of operations were adversely affected by Chesapeake Energys reduced natural gas drilling activity.
The loss of key contracts could adversely impact our financial condition and results of operations.
Contracts with customers of our environmental solutions business generally have initial terms of one to three years, with renewal options
and early termination clauses. Although we have experienced growth in the number of companies using our services during 2012, the loss or material reduction of business could adversely affect our financial condition and results of operations. We
cannot assure you that our existing contracts will continue or be extended or renewed, that existing customers will continue to use our services at current levels or that we will be successful in obtaining new contracts.
Our ability to utilize net operating loss carryforwards in the future may be subject to substantial limitations.
The company believes that its ability to use its U.S. federal net operating loss carryforwards and other tax attributes may be limited.
Internal Revenue Code Sections 382 and 383 provide annual limitations with respect to the ability of a corporation to utilize its net operating loss (as well as certain built-in losses) and tax credit carryforwards, respectively (Tax Attributes),
against future U.S. taxable income, if the corporation experiences an ownership change. In general terms, an ownership change may result from transactions increasing the ownership of certain stockholders in the stock of a corporation by
more than 50 percentage points over a three-year period. The company regularly monitors ownership changes (as calculated for purposes of Section 382). Based on currently available information, the company believes that an ownership change may
have occurred during 2012, for purposes of the rules described above. Moreover, any future transaction or transactions and the timing of such transaction or transactions could trigger additional ownership changes under Section 382. In the
event of an ownership change, utilization of the companys Tax Attributes will be subject to an overall annual limitation determined in part by multiplying the total adjusted aggregate market value of the companys common stock immediately
preceding the ownership change by the applicable long-term tax-exempt rate, possibly subject to increase based on the built-in gain, if any, in the companys assets at the time of the ownership change. Any unused annual limitation may be
carried over to later years. Future U.S. taxable income may not be fully offset by existing Tax Attributes, if such income exceeds the companys annual limitation.
We operate in competitive markets, and there can be no certainty that we will maintain our current customers or attract new customers or that our operating margins will not be impacted by
competition.
The industries in which our Fluids Management and Recycling businesses operate are highly competitive.
We compete with numerous local and regional companies of varying sizes and financial resources. We expect competition to intensify in the future. Furthermore, numerous well-established companies are focusing significant resources on providing
similar services to those that we provide that will compete with our services. We cannot assure you that we will be able to effectively compete with these other companies or that competitive pressures, including possible downward pressure on the
prices we charge for our products and services, will not arise. In the event that we cannot effectively compete on a continuing basis, or competitive pressures arise, such inability to compete or competitive pressures could have a material adverse
effect on our business, results of operations and financial condition.
Our Fluids Management business depends on spending by the oil
and natural gas industry in the United States, and this spending and our business has been, and may continue to be, adversely affected by industry and financial market conditions that are beyond our control.
We depend on our customers willingness to make operating and capital expenditures to explore, develop and produce oil and natural
gas in the United States. Declines in these expenditures, due to the low natural gas price environment or other factors, could result in project modification, delays or cancellations, general business disruptions, and delays in, or nonpayment of,
amounts owed to us. Customers expectations for lower market prices for oil and natural gas, as well as the availability of capital for operating and capital expenditures, may also cause our customers to curtail spending, thereby reducing
demand for our services.
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Industry conditions are influenced by numerous factors over which we have no control,
including:
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the domestic and worldwide price and supply of natural gas, natural gas liquids and oil, including the natural gas inventories and oil reserves of the
United States;
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changes in the level of consumer demand;
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the price and availability of alternative fuels;
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the availability, proximity and capacity of pipelines, other transportation facilities and processing facilities;
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the level and effect of trading in commodity futures markets, including by commodity price speculators and others;
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the nature and extent of domestic and foreign governmental regulations and taxes;
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the ability of the members of OPEC to agree to and maintain oil price and production controls;
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political instability or armed conflict in oil and natural gas producing regions
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currency exchange rates; and
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overall domestic and global economic and market conditions.
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The volatility of the oil and natural gas industry and the impact on exploration and production activity could adversely impact the level of drilling activity by some of our customers or in some of the
regions in which we operate. For example, natural gas spot prices have fallen significantly since late 2011 and the number of active drilling rigs operating in the Haynesville, Barnett and Marcellus Shale areas has declined with many of these rigs
moving to other oil- and liquids-rich shale areas such as the Utica, Eagle Ford, Bakken and Permian Basin. This transition in exploration and production activity has caused and may continue to cause a decline in the demand for our services in
affected regions where we operate and has adversely affected and may continue to affect the price of our services and the financial results of our operations. In addition, reduced discovery rates of new oil and natural gas reserves in our market
areas also may have a negative long-term impact on our business, even in an environment of stronger oil and natural gas prices, due to reduced fracking activity and reduced produced water from existing producing wells to the extent existing
production is not replaced and the number of producing wells for us to service declines.
Recent declines in natural gas
prices have caused many oil and natural gas producers to announce reductions in capital budgets for future periods. Limitations on the availability of capital, or higher costs of capital, for financing expenditures may cause these and other oil and
natural gas producers to make additional reductions to capital budgets in the future even if commodity prices increase from current levels. These cuts in spending have curtailed drilling programs as well as discretionary spending on well services,
which have also adversely affected and may continue to affect the demand for our services, the rates we can charge and our utilization. In addition, certain of our customers could become unable to pay their vendors and service providers, including
us, and we increased our bad debt reserve in 2011 and 2012 to reflect this development. Any of these conditions or events could adversely affect our operating results and cash flows.
Any interruption in our Fluids Management services due to pipeline ruptures or spills or necessary maintenance could impair our financial performance and negatively affect our brand.
Our fixed water transport pipelines are susceptible to ruptures and spills, particularly during start up and initial
operation, and require ongoing inspection and maintenance. For example, in 2010 and 2011, we had breaks in our 50-mile underground pipeline network in the Haynesville Shale area that resulted in delays in transporting our customers water and
resulted in significant repair and remediation costs. We may experience further difficulties in maintaining the operation of our pipelines, which may cause downtime and delays. Any interruption in our services due to pipeline breakdowns or necessary
maintenance could reduce sales revenues and earnings and result in remediation costs. Transportation interruptions at our pipelines, even if only temporary, could severely harm our business and reputation.
Our operations are subject to risks inherent in the oil and natural gas industry, some of which are beyond our control. These risks may not be
fully covered under our insurance policies.
Our operations are subject to operational hazards, including accidents or
equipment issues that can cause pollution and other damage to the environment. For example, produced water from our pipelines has leaked into private property on several occasions. As required pursuant to applicable law, we remediated the
environmental impact, including related to site investigation and soil, groundwater and surface water cleanup.
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In addition, hazards inherent in the oil and natural gas industry, such as, but not limited
to, accidents, blowouts, explosions, pollution and other damage to the environment, fires and hydrocarbon spills, may delay or halt operations at extraction sites which we service. These conditions can cause:
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personal injury or loss of life;
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liabilities from pipeline breaks and accidents by our fleet of trucks and other equipment;
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damage to or destruction of property, equipment and the environment; and
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the suspension of operations.
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The occurrence of a significant event or a series of events that together are significant, or adverse claims in excess of the insurance coverage that we maintain or that are not covered by insurance,
could have a material adverse effect on our financial condition and results of operations. In addition, claims for loss of oil and natural gas production and damage to formations can occur in the well services industry. Litigation arising from a
catastrophic occurrence at a location where our equipment and services are being used may result in our being named as a defendant in lawsuits asserting large claims.
The Companys maintains insurance coverage that we believe to be customary in the industry against these hazards. We may not be able to maintain adequate insurance in the future at rates we consider
reasonable. In addition, insurance may not be available to cover any or all of the risks to which we are subject, or, even if available, it may be inadequate, or insurance premiums or other costs could make such insurance prohibitively expensive. It
is likely that, in our insurance renewals, our premiums and deductibles will be higher, and certain insurance coverage either will be unavailable or considerably more expensive than it has been in the recent past. In addition, our insurance is
subject to coverage limits, and some policies exclude coverage for damages resulting from environmental contamination.
Improvements in
or new discoveries of alternative energy technologies or fracking methodologies could have a material adverse effect on our financial condition and results of operations.
Because our Fluids Management segment depends on the level of activity in the oil and natural gas industry, any improvement in or new
discoveries of alternative energy technologies (such as wind, solar, geothermal, fuel cells and biofuels) that increase the use of alternative forms of energy and reduce the demand for oil and natural gas could have a material adverse impact on our
business, financial condition and results of operations. In addition, technological changes could decrease the quantities of water required for fracking operations or otherwise affect demand for our services.
Seasonal weather conditions and natural disasters could severely disrupt normal operations and harm our business.
We operate in the southern, mid-western, western and eastern United States. These areas are adversely affected by seasonal weather
conditions, primarily in the winter and spring. During periods of heavy snow, ice or rain, our customers may curtail their operations or we may be unable to move our trucks between locations or provide other services, thereby reducing demand for, or
our ability to provide services and generate revenues. For example, many municipalities impose weight restrictions on the paved roads that lead to our customers jobsites in the spring due to the muddy conditions caused by spring thaws,
limiting our access and our ability to provide service in these areas. In February 2011, portions of Texas had record snowfalls. In September 2011 and October 2012, portions of Pennsylvania and other areas in the eastern United States had record
rainfall and flooding. During those periods, we and our customers had to significantly reduce or halt operations, resulting in a loss of revenue. In addition, the regions in which we operate have in the past been, and may in the future be, affected
by natural disasters such as hurricanes, windstorms, floods and tornadoes; in 2005 and 2008, for example, tropical hurricanes and related storm activity caused extensive damage in portions of Texas and Louisiana, causing disruptions in our, and our
customers, operations. Future natural disasters or inclement weather conditions could severely disrupt the normal operation of our, or our customers, business and have a material adverse effect on our financial condition and results of
operations.
Our operating margins and profitability may be negatively impacted by changes in fuel and energy costs, in part due to the
fixed cost structure of our business.
Our Recycling business is dependent on the widespread availability of certain
crude oil products such as UMO and both our Recycling and Fluids Management business are depending on the availability of fuel for operating our fleet of trucks. Changes and volatility in the price of crude can adversely impact the prices for these
products and therefore affect our operating results. The price and supply of fuel is unpredictable and fluctuates based on events beyond our control, including geopolitical developments, supply and demand for oil and gas, actions by OPEC and other
oil and gas producers, war and unrest in oil producing countries, regional production patterns, and environmental concerns.
In addition, the price at which we sell our RFO can be affected by changes in certain oil indices. If the relevant oil index rises, we
can typically increase prices for our RFO. If the relevant oil index declines, we must typically reduce prices for our RFO. However, the cost to collect UMO, including the amounts we must pay to obtain UMO and the fuel costs of our oil collection
fleet,
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generally also increases or decreases when the relevant index increases or decreases. Even though the prices we can charge for our RFO and the costs to collect and process UMO generally increase
and decrease together, we cannot assure you that when our costs to collect and process UMO increase we can increase the prices we charge for our RFO to cover such increased costs or that the costs to collect and process UMO will decline when the
prices we can charge for processed oil declines, which could adversely affect our profit margins. If the prices we charge for our RFO and the costs to collect and process UMO do not move together or in similar magnitudes, it could adversely affect
our profit margins, financial condition and results of operations. In addition, falling oil and diesel prices could make diesel more cost competitive with RFO, which could adversely affect our Recycling Division segment operating results.
Furthermore, our facilities, fleet and personnel subject us to fixed costs, which make our margins and earnings sensitive to
changes in revenues. In periods of declining demand, our fixed cost structure may limit our ability to cut costs, which may put us at a competitive disadvantage to firms with lower cost structures, or may result in reduced operating margins and/or
operating losses.
Consolidation and/or declines in the United States automotive repair and manufacturing industries could cause us to
experience lower sales volumes, which could materially affect our growth and financial performance.
Our Recycling
Division relies on continued demand for oil collection, environmental and waste management services in the United States automotive repair and manufacturing industries, which may suffer from declining market size and number of locations, due in part
to the uncertainty of economic conditions, international competition, and consolidation. Industry trends affecting our customers have caused our customers businesses to contract. Additional decline could reduce the demand for our parts
cleaning and other services and products and have a material adverse impact on our business. As a result, we may not be able to continue to grow our business by increasing penetration into the industries which we serve, and our ability to retain our
market share and base of sales could become more difficult.
The price we receive for our RFO depends on numerous factors beyond our
control, such as the supply and demand of asphalt, paper and pulp.
The price of RFO and other refined products
depends on numerous factors beyond our control, including the supply and demand of asphalt, paper and pulp and other industrial products, in general. Our Recycling Division supplies a large percentage of its RFO for use in the production of asphalt
and paper and pulp. Changes in the supply and demands for these products may, in turn, drive the price of RFO down, which could have an adverse effect on the results of our Recycling Division. The supply and demand of asphalt, for example, is
affected by, among other things, local economic conditions, federal, state and local spending on infrastructure development, housing starts, federal highway trust funds, and seasonality, with demand for asphalt and asphalt products generally being
higher during the summer months, due to increases in highway traffic and road construction work. Likewise, the supply and demand of paper and pulp is affected by, among other things, costs of wood, logging and transportation of timber, price of
market pulp, cyclical changes in the global economy, industry capacity, foreign exchange rates, levels of economic growth and climate change, as well as social and government responses to climate change.
The inability of our Recycling Division to source adequate volumes of UMO to generate profits or contributions from the sale of RFO could have a
material adverse effect on our financial condition and results of operations.
Our Recycling Division is dependent on
the availability of UMO. If our Recycling Division is not able to source adequate volumes of UMO from generators or other third parties at acceptable prices to generate profits or contributions from the subsequent sale of RFO, we could experience a
material adverse effect on our financial condition and results of operations.
Nonconforming or contaminated materials that we may
receive from our Recycling customers may expose us to earnings impairments.
Our Recycling Division relies, in part,
on materials, particularly UMO, provided by our customers. From time to time, customers tender nonconforming materials that could be contaminated with toxins (e.g. polychlorinated biphenyls and other non-value added waste streams). It is possible
that the costs associated with remediation and business interruption due to this contamination and any associated regulatory fines could be in excess of our insurance coverage limits, thus exposing us to earnings impairments.
Litigation related to personal injury from the operation of our Recycling business may result in significant liabilities and limit our
profitability.
The hazards and risks associated with the use, transport, storage, and handling and disposal of our
customers waste (such as fires, natural disasters, explosions and accidents) may expose us to personal injury claims, property damage claims and/or products liability claims from our customers or third parties. As protection against such
claims and operating hazards, we maintain insurance coverage against some, but not all, potential losses. However, we may sustain losses for uninsurable or uninsured risks, or in amounts in excess of existing insurance coverage. Due to the
unpredictable nature of personal injury litigation, it is not possible to predict the ultimate outcome of these claims and lawsuits, and we may be held liable for significant personal injury or damage to property or third parties, or other losses,
that are not fully covered by our insurance, which could have a material adverse effect on our business.
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Our Recycling Division is dependent on third parties to supply us with the necessary components and
materials to service our customers as well as on third party transport, recycling and disposal contractors.
If we are
unable to obtain adequate supplies and components in a timely and cost-effective manner, we may be unable to adequately provide sufficient quantities of our services and products to our customers, which could have a material adverse effect on our
financial condition and results of operations. We, and our third party transporters, ship used oil and containerized waste collected from our customers to a number of third party recycling and disposal facilities, including incinerators, landfill
operators and waste-to-energy facilities. We generally do not have long-term fixed price contracts with our third party contractors, and if we are forced to seek alternative vendors to handle our third party recycling and disposal activities, we may
not be able to find alternatives without significant additional expenses, or at all, which could result in a material adverse effect on our financial performance. In addition, we could be subject to significant environmental liabilities from claims
relating to the transport, storage, processing, recycling and disposal of our customers waste by our third party contractors and their subcontractors.
We are subject to potential indemnification and warranty and product liability claims relating to our services and products.
Generally, our contracts with our customers provide that in certain circumstances we will be responsible for expenses resulting from,
among other things, a spill that occurs while we are transporting, processing or disposing of customers oil, used solvent and other waste, or any other damage to property, death or harm to any person, contamination of or adverse effects to the
environment, or violation of governmental laws or rules. Accordingly, in that situation we may be required to indemnify our customers for liability under CERCLA or other environmental, employment, health and safety laws and regulations, as a result
of our own willful misconduct or negligence. We may also be exposed to warranty or product liability claims by our customers, users of our parts cleaning antifreeze sales, oily water collection, oil filter collection and processing and products or
third parties claiming damages stemming from the mechanical failure of parts cleaned with solvents and/or equipment provided by us. Although we maintain product liability insurance coverage, if our insurance coverage proves inadequate or adequate
insurance becomes unreasonably costly or otherwise unavailable, future claims may not be fully insured. An uninsured or partially insured successful claim against us could have a material adverse effect on our business, financial condition and
results of operations.
Security breaches and other disruptions could compromise our information and expose us to liability, which would
cause our business and reputation to suffer.
In the ordinary course of business, we collect and store sensitive data,
including intellectual property, our proprietary business information and that of our customers, suppliers and business partners, and personally identifiable information of our customers and employees, in our data centers and on our networks. The
secure processing, maintenance and transmission of this information is critical to our operations and business strategy. Despite our security measures, our information technology and infrastructure may be vulnerable to attacks by hackers or breached
due to employee error, malfeasance or other disruptions. Any such breach could compromise our networks and the information stored there could be accessed, publicly disclosed, lost or stolen. Any such access, disclosure or other loss of information
could result in legal claims or proceedings, liability under laws that protect the privacy of personal information, and regulatory penalties, disrupt our operations and the services we provide to customers, and damage our reputation, and cause a
loss of confidence in our products and services, which could adversely affect our business/operating margins, revenues and competitive position.
Risks Related to Our Indebtedness
Our substantial level of indebtedness could
adversely affect our financial condition and prevent us from fulfilling our obligations under our indebtedness.
As of
December 31, 2012, we had approximately $566.1 million of indebtedness, net of premiums and discounts, outstanding on a consolidated basis, of which approximately $167.0 million was secured, including $147.0 million outstanding under our $325.0
million senior secured revolving credit facility, which we refer to as the Amended Revolving Credit Facility and $20.0 million of capital leases for new trucks acquired in 2012 and other vehicle financings. Borrowings under our Amended
Revolving Credit Facility effectively rank senior to our unsecured indebtedness, including our $400.0 million aggregate principal amount of 9.875% Senior Notes due 2018, or the 2018 Notes, to the extent of the value of the assets
securing such debt. We have approximately $177.0 million of additional availability (less approximately $1.0 million used for letters of credit) under our Amended Revolving Credit Facility. Our substantial level of indebtedness increases the risk
that we may be unable to generate cash sufficient to pay amounts due in respect of our indebtedness. Our substantial level of indebtedness could have other important consequences. For example, our level of indebtedness and the terms of our debt
agreements may:
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make it more difficult for us to satisfy our financial obligations under our other indebtedness and our contractual and commercial commitments and
increase the risk that we may default on our debt obligations;
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prevent us from raising the funds necessary to repurchase the 2018 Notes tendered to us if there is a change of control, which would constitute a
default under the indenture governing the 2018 Notes;
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heighten our vulnerability to downturns in our business, our industry or in the general economy and restrict us from exploiting business opportunities
or making acquisitions;
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limit managements discretion in operating our business;
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require us to dedicate a substantial portion of our cash flow from operations to payments on our indebtedness, thereby reducing the availability of our
cash flow to fund working capital, capital expenditures, and other general corporate purposes;
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require us to dedicate a substantial portion of our cash flow from operations to payments on our indebtedness, thereby reducing the availability of our
cash flow to fund working capital, capital expenditures, and other general corporate purposes;
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place us at a competitive disadvantage compared to our competitors that have less debt;
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limit our ability to borrow additional funds; and
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limit our flexibility in planning for, or reacting to, changes in our business, the industry in which we operate or the general economy.
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Each of these factors may have a material and adverse effect on our financial condition and viability. Our
ability to make payments with respect to the 2018 Notes and to satisfy our other debt obligations will depend on our future operating performance, which will be affected by prevailing economic conditions and financial, business and other factors
affecting our Company and industry, many of which are beyond our control. In addition, the indenture governing the 2018 Notes and the Amended Revolving Credit Facility contain financial and other restrictive covenants that will affect our ability to
engage in activities that may be in our long-term best interests. Our failure to comply with those covenants could result in an event of default that, if not cured or waived, could result in the acceleration of all of our debt.
Borrowings under our Amended Credit Facility bear interest at variable rates. If we were to borrow funds and these rates were to increase
significantly, our ability to borrow additional funds may be reduced and the risks related to our substantial indebtedness would intensify. While we may enter into agreements limiting our exposure to higher interest rates, any such agreements may
not offer complete protection for this risk.
Despite existing debt levels, we may still be able to incur substantially more debt, which
would increase the risks associated with our leverage.
Even with our existing debt levels, we and our subsidiaries
may be able to incur substantial amounts of additional debt in the future, some or all of which may be secured. As of December 31, 2012 we had approximately $177.0 million of borrowing availability (less approximately $1.0 million used for
letters of credit) under our Amended Credit Facility. In addition, the indenture governing the 2018 Notes and the Amended Credit Facility allow us to issue additional debt, including additional notes, under certain circumstances, which may be
guaranteed by our subsidiaries. Although the terms of the Amended Credit Facility and the indenture governing the 2018 Notes limit our ability to incur additional debt, these terms do not and will not prohibit us from incurring substantial amounts
of additional debt for specific purposes or under certain circumstances, some or all of which may be secured. If new debt is added to our and our subsidiaries current debt levels, the related risks that we and they now face could intensify and
could further exacerbate the risks associated with our leverage.
We may not be able to generate sufficient cash flow to meet our debt
service, lease payments and other obligations due to events beyond our control.
We expect our interest expense
related to the 2018 Notes, the borrowings under our Amended Credit Facility as of December 31, 2012, and our other indebtedness, including indebtedness assumed in connection with the Merger, to increase to approximately $47.7 million per year,
and we will have higher lease expenses and other obligations after consummation of the Merger. Our ability to generate cash flows from operations, to make scheduled payments on or refinance our indebtedness and to fund working capital needs and
planned capital expenditures will depend on our future financial performance and our ability to generate cash in the future. Our future financial performance will be affected by a range of economic, financial, competitive, business and other factors
that we cannot control, such as general economic, legislative, regulatory and financial conditions in our industry, the economy generally or other risks described in our reports filed with the SEC. A significant reduction in operating cash flows
resulting from changes in economic, legislative or regulatory conditions, increased competition or other events beyond our control could increase the need for additional or alternative sources of liquidity and could have a material adverse effect on
our business, financial condition, results of operations, prospects and our ability to service our debt and other obligations. If we are unable to service our indebtedness or to fund our other liquidity needs, we may be forced to adopt an
alternative strategy that may include actions such as reducing or delaying capital expenditures, selling assets, restructuring or refinancing our indebtedness, seeking additional capital, or any combination of the
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foregoing. If we raise additional debt, it would increase our interest expense, leverage and our operating and financial costs. We cannot assure you that any of these alternative strategies could
be effected on satisfactory terms, if at all, or that they would yield sufficient funds to make required payments on our indebtedness or to fund our other liquidity needs. Reducing or delaying capital expenditures or selling assets could delay
future cash flows. In addition, the terms of existing or future debt agreements may restrict us from adopting any of these alternatives. We cannot assure you that our business will generate sufficient cash flows from operations or that future
borrowings will be available in an amount sufficient to enable us to pay our indebtedness or to fund our other liquidity needs.
If for any reason we are unable to meet our debt service and repayment obligations, we would be in default under the terms of the
agreements governing our indebtedness, which would allow our creditors at that time to declare all outstanding indebtedness to be due and payable. This would likely in turn trigger cross-acceleration or cross-default rights between our applicable
debt agreements. Under these circumstances, our lenders could compel us to apply all of our available cash to repay our borrowings or they could prevent us from making payments on the 2018 Notes or our other indebtedness. In addition, the lenders
under our Amended Credit Facility or other secured indebtedness could seek to foreclose on our assets that are their collateral. If the amounts outstanding under our indebtedness were to be accelerated, or were the subject of foreclosure actions, we
cannot assure you that our assets would be sufficient to repay in full the money owed to the lenders or to our other debt holders.
The
Amended Credit Facility and the indenture governing the 2018 Notes impose significant operating and financial restrictions on us and our subsidiaries that may prevent us from pursuing certain business opportunities and restrict our ability to
operate our business.
The Amended Credit Facility and the indenture governing the 2018 Notes contain covenants that
restrict our and our restricted subsidiaries ability to take various actions, such as:
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transferring or selling assets;
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paying dividends or distributions, buying subordinated indebtedness or securities, making certain investments or making other restricted payments;
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incurring or guaranteeing additional indebtedness or issuing preferred stock;
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creating or incurring liens;
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incurring dividend or other payment restrictions affecting restricted subsidiaries;
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consummating a merger, consolidation or sale of all or substantially all our assets;
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entering into transactions with affiliates;
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engaging in business other than a business that is the same or similar, reasonably related, complementary or incidental to our business;
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designating subsidiaries as unrestricted subsidiaries;
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making capital expenditures;
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entering into sale and leaseback transactions; and
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prepaying, redeeming or repurchasing debt prior to stated maturities.
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In addition, our Amended Credit Facility requires, and any future credit facilities will likely require, us to maintain minimum cash
balances and operating performance levels and comply with specified financial ratios, including regarding net leverage, debt to capitalization, fixed charge coverage or similar ratios. A breach of any of the foregoing covenants under the
indenture governing the Notes or the Amended Credit Facility, as applicable, could result in a default. In addition, any debt agreements we enter into in the future may further limit our ability to enter into certain types of transactions.
We may also be prevented from taking advantage of business opportunities that arise if we fail to meet certain ratios or
because of the limitations imposed on us by such restrictive covenants. These restrictions may also limit our ability to plan for or react to market conditions, meet capital needs or otherwise restrict our activities or business plans and adversely
affect our ability to finance our operations, enter into acquisitions, execute our business strategy, effectively compete with companies that are not similarly restricted or engage in other business activities that would be in our interest. In the
future, we may also incur debt obligations that
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might subject us to additional and different restrictive covenants that could affect our financial and operational flexibility. We cannot assure you that we will be granted waivers or amendments
to the indenture governing the 2018 Notes, the Amended Credit Facility or such other debt obligations if for any reason we are unable to comply with our obligations thereunder or that we will be able to refinance our debt on acceptable terms or at
all should we seek to do so.
The covenants described above are subject to important exceptions and qualifications. Our
ability to comply with these covenants will likely be affected by events beyond our control, and we cannot assure you that we will satisfy those requirements. A breach of any of these provisions could result in a default under such indenture,
Amended Credit Facility or other debt obligation, or any future credit facilities we may enter into, which could allow all amounts outstanding thereunder to be declared immediately due and payable, subject to the terms and conditions of the
documents governing such indebtedness. If we were unable to repay the accelerated amounts, our secured lenders could proceed against the collateral granted to them to secure such indebtedness. This would likely in turn trigger cross-acceleration and
cross-default rights under any other credit facilities and indentures. If the amounts outstanding under the 2018 Notes or any other indebtedness outstanding at such time were to be accelerated or were the subject of foreclosure actions, we cannot
assure you that our assets would be sufficient to repay in full the money owed to the lenders or to our other debt holders.
Our
borrowings under our Amended Credit Facility expose us to interest rate risk.
Our earnings are exposed to interest
rate risk associated with borrowings under our Amended Credit Facility. Our Amended Credit Facility carries a floating interest rate; therefore, as interest rates increase, so will our interest costs, which may have a material adverse effect on our
results of operations and financial condition. We have not yet decided whether or not we will engage in hedging activity with respect to our Amended Credit Facility.
Risks Related to Our Common Stock
We may issue a substantial number of shares of
our common stock in the future and stockholders may be adversely affected by the issuance of those shares.
We may
raise additional capital by issuing shares of common stock, which will increase the number of common shares outstanding and may result in dilution in the equity interest of our current stockholders and may adversely affect the market price of our
common stock. We have filed a registration statement on Form S-4 with the SEC which allows us, in connection with acquisitions, to issue up to 15.0 million shares of common stock that are freely tradable upon issuance. As of December 31,
2012, we had issued approximately 7.0 million shares of our common stock under this registration statement and had approximately 8.0 million shares remaining available for future issuance. We have also filed a shelf registration statement on Form
S-3 with the SEC which allows us to issue up to $400.0 million in debt, equity and hybrid securities. As of December 31, 2012, we had issued 18,200,000 shares of common stock at total price of $80.08 million, under this registration statement
and could issue up to an additional $319.92 million of debt, equity or hybrid securities. In addition, we have issued shares of our common stock pursuant to private placement exemptions from Securities Act registration requirements, including
95.0 million shares issued in connection with the Power Fuels merger, and may do so in the future. The issuance, and the resale or potential resale, of shares of our common stock in connection with acquisitions or otherwise could adversely
affect the market price of our common stock, and could be dilutive to our stockholders depending on the performance of the acquired business and other factors.
Our stock price may be volatile, which could result in substantial losses for investors in our securities.
The stock markets have experienced extreme volatility that has often been unrelated to the operating performance of particular companies. These broad market fluctuations may adversely affect the trading
price of our common stock.
The market price of our common stock may also fluctuate significantly in response to the following
factors, some of which are beyond our control:
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variations in our quarterly operating results;
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changes in securities analysts estimates of our financial performance;
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changes in market valuations of similar companies;
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announcements by us or our competitors of significant contracts, acquisitions, strategic partnerships, joint ventures, capital commitments, new
products or product enhancements;
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changes in the price of oil and natural gas;
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loss of a major customer or failure to complete significant transactions; and
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additions or departures of key personnel.
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22
The trading price of our common stock on the New York Stock Exchange, or NYSE,
since our initial public offering has ranged from a high of $10.74 on September 3, 2008 to a low of $2.60 on August 7, 2012. The last reported price of our common stock on the NYSE on March 14, 2013 was
$4.32
per share.
We currently do not intend to pay any dividends on our common stock.
We currently do not intend to pay any dividends on our common stock, and restrictions and covenants in our commercial credit facilities
may prohibit us from paying dividends now or in the future. While we may declare dividends at some point in the future, subject to compliance with such restrictions and covenants, we cannot assure you that you will ever receive cash dividends as a
result of ownership of our common stock and any gains from investment in our common stock may only come from increases in our stock prices, if any.
We are subject to anti-takeover effects of certain charter and bylaw provisions and Delaware law, as well as of our substantial insider ownership.
Provisions of our certificate of incorporation and bylaws, each as amended and restated, and Delaware law may discourage, delay or
prevent a merger or acquisition that stockholders may consider favorable, including transactions in which you might otherwise receive a premium for your shares. In addition, these provisions may frustrate or prevent any attempts by our stockholders
to replace or remove our management and board of directors. These provisions include:
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authorizing the issuance of blank check preferred stock without any need for action by stockholders;
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establishing a classified board of directors, so that only approximately one-third of our directors are elected each year;
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providing our board of directors the ability to set the number of directors and to fill vacancies on the board of directors occurring between
stockholder meetings;
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providing that directors may only be removed only for cause and only by the affirmative vote of the holders of at least a majority in
voting power of our issued and outstanding capital stock; and
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limiting the ability of our stockholders to call special meetings.
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We are also subject to provisions of the Delaware corporation law that, in general, prohibit any business combination with a beneficial
owner of 15% or more of our common stock for three years following the date the beneficial owner acquired at least 15% of our stock, unless various conditions are met, such as approval of the transaction by our board of directors. Together, these
charter and statutory provisions could make the removal of management more difficult and may discourage transactions that otherwise could involve payment of a premium over prevailing market prices for our common stock.
The existence of the foregoing provisions and anti-takeover measures, as well as the significant common stock beneficially owned by our
Chief Executive Officer and Vice Chairman, Mr. Johnsrud, could limit the price that investors might be willing to pay in the future for shares of our common stock. They could also deter potential acquirers of our company, thereby reducing the
likelihood that you could receive a premium for your common stock in an acquisition.
Risks Related to Environmental and
Other Governmental Regulation
We are subject to United States federal, state and local laws and regulations relating to health,
safety, transportation, and protection of natural resources and the environment. Under these laws and regulations, we may become liable for significant penalties, damages or costs of remediation. Any changes in laws and regulations could increase
our costs of doing business.
Our operations, and those of our customers, are subject to United States federal, state
and local laws and regulations relating to health, safety, transportation and protection of natural resources and the environment and worker safety, including those relating to waste management and transportation and disposal of produced water and
other materials. For example, we are subject to environmental regulation relating to disposal into injection wells, which can pose some risks of environmental liability, including leakage from the wells to surface or subsurface soils, surface water
or groundwater. Liability under these laws and regulations could result in cancellation of well operations, fines and penalties, expenditures for remediation, and liability for property damage and personal injuries.
Our businesses, in particular our Recycling business, involve the use, handling, storage, and contracting for recycling or disposal of
environmentally sensitive materials, such as motor oil, waste motor oil and filters, solvents, transmission fluid, antifreeze, lubricants, degreasing agents, gasoline, and diesel fuels. Accordingly, we are subject to regulation by federal, state,
and local authorities establishing investigation and health and environmental quality standards, and liability related thereto, and providing penalties for violations of those standards. We also are subject to laws, ordinances, and regulations
governing investigation and
23
remediation of contamination at facilities we operate or to which we send hazardous or toxic substances or wastes for treatment, recycling, or disposal. In particular, CERCLA imposes joint,
strict, and several liability on owners or operators of facilities at, from, or to which a release of hazardous substances has occurred; parties that generated hazardous substances that were released at such facilities; and parties that transported
or arranged for the transportation of hazardous substances to such facilities. A majority of states have adopted statutes comparable to and, in some cases, more stringent than CERCLA. If we were to be found to be a responsible party under CERCLA or
a similar state statute, we could be held liable for all investigative and remedial costs associated with addressing such contamination. In addition, claims alleging personal injury or property damage may be brought against us as a result of alleged
exposure to hazardous substances resulting from our operations.
Failure to comply with these laws and regulations could
result in the assessment of significant administrative, civil or criminal penalties, imposition of cleanup and site restoration costs and liens, revocation of permits, and orders to limit or cease certain operations. In addition, certain
environmental laws impose strict and/or joint and several liability, which could cause us to become liable for the conduct of others or for consequences of our own actions that were in compliance with all applicable laws at the time of those
actions. For example, if a landfill or disposal operator mismanages our wastes in a way that creates an environmental hazard, we and all others who sent materials could become liable for cleanup costs, fines and other expenses many years after the
disposal or recycling was completed. Future events, such as the discovery of currently unknown matters, spills caused by future pipeline ruptures, changes in existing environmental laws and regulations or their interpretation, and more vigorous
enforcement policies by regulatory agencies, may give rise to additional expenditures or liabilities, which could impair our operations and adversely affect our business and results of operations.
Although we believe that we are in substantial compliance with all applicable laws and regulations, legal requirements are changing
frequently and are subject to interpretation. New laws, regulations and changing interpretations by regulatory authorities, together with uncertainty regarding adequate testing and sampling procedures, new pollution control technology and cost
benefit analysis based on market conditions are all factors that may increase our future capital expenditures to comply with environmental requirements. Accordingly, we are unable to predict the ultimate cost of future compliance with these
requirements or their effect on our operations.
Increased regulation of hydraulic fracturing, including regulation of the quantities,
sources and methods of water use and disposal, could result in reduction in drilling and completing new oil and natural gas wells or minimize water use or disposal, which could adversely impact the demand for our Fluids Management services.
Demand for our Fluids Management services depends, in large part, on the level of exploration and production of oil
and gas and the oil and gas industrys willingness to purchase our services. Most of our customer base uses hydraulic fracturing to drill new oil and gas wells. Hydraulic fracturing is a process that is used to release hydrocarbons,
particularly natural gas, from certain geological formations. The process involves the injection of water (typically mixed with significant quantities of sand and small quantities of chemical additives) under pressure into the formation to fracture
the surrounding rock and stimulate movement of hydrocarbons through the formation. The process is typically regulated by state oil and gas commissions and has been exempt (except when the fracturing fluids or propping agents contain diesel fuels)
since 2005 from United States federal regulation pursuant to the SWDA.
The EPA is conducting a comprehensive study of the
potential environmental impacts of hydraulic fracturing activities, and a committee of the United States House of Representatives is also conducting an investigation of hydraulic fracturing practices. The results of the EPA study and House
investigation could lead to restrictions on hydraulic fracturing. The EPA is currently working on new guidance for application of SWDA permits for drilling or completing processes that use fracturing fluids or propping agents containing diesel
fuels. In addition, the EPA finalized regulations under the CAA in October 2012 regarding certain criteria and hazardous air pollutant emissions from hydraulic fracturing wells and, in October 2011, announced its intention to propose regulations by
2014 under the CWA to regulate wastewater discharges from hydraulic fracturing and other gas production. Legislation has been introduced before Congress to provide for federal regulation of hydraulic fracturing, including, for example, requiring
disclosure of chemicals used in the fracturing process or seeking to repeal the exemption from the SWDA. If adopted, such legislation would add an additional level of regulation and necessary permitting at the federal level and could make it more
difficult to complete wells using hydraulic fracturing. Similar laws and regulations with respect to chemical disclosure also exist or are being considered by the United States Department of Interior and in several states, including certain states
in which we operate, that could restrict hydraulic fracturing. The Delaware River Basin Commission is also considering regulations which may impact hydrofracturing water practices in certain areas of Pennsylvania, New York, New Jersey
and Delaware. Some local governments have also sought to restrict drilling in certain areas.
Future United States federal,
state or local laws or regulations could significantly restrict, or increase costs associated with hydraulic fracturing and make it more difficult or costly for producers to conduct hydraulic fracturing operations, which could result in a decline in
exploration and production. New laws and regulations, and new enforcement policies by regulatory agencies, could also expressly restrict the quantities, sources and methods of water use and disposal in hydraulic fracturing and otherwise increase our
costs and our customers cost of compliance, which could minimize water use and disposal needs even if other limits on drilling and completing new wells were not imposed. Any decline in exploration and production or any restrictions on water
use and disposal could result in a decline in demand for our services and have a material adverse effect on our business, financial condition, results of operations and cash flows.
24
Delays or restrictions in obtaining permits by our customers for their operations or by us for our
operations could impair our business.
In most states, our customers are required to obtain permits from one or more
governmental agencies in order to perform drilling and completion activities and we may be required to procure permits for construction and operation of our disposal wells and pipelines. Such permits are typically required by state agencies, but can
also be required by federal and local governmental agencies. The requirements for such permits vary depending on the location where our, or our customers, activities will be conducted. As with all governmental permitting processes, there is a
degree of uncertainty as to whether a permit will be granted, the time it will take for a permit to be issued, and the conditions which may be imposed in connection with the granting of the permit. Delays or restrictions in obtaining salt water
disposal well permits could adversely impact our growth, which is dependent in part on new disposal capacity.
Our customers
have been affected by moratoriums on the issuance of permits that have been imposed upon drilling and completion activities in certain jurisdictions. For example, in December 2010, the State of New York imposed a moratorium on certain drilling and
completion activities. In 2011, the state announced plans to lift the moratorium, however, there is a proposal in the New York legislature to extend the moratorium for another year and, as of March 1, 201, the moratorium had not been lifted. A
similar moratorium has been in place within the Delaware River Basin pending issuance of regulations by the Delaware River Basin Commission. Other states, including Texas, Arkansas, Pennsylvania, Wyoming and Colorado, have enacted laws and
regulations applicable to our business activities, including disclosure of information regarding the substances used in hydraulic fracturing. California is presently considering similar requirements. Some of the drilling and completion activities of
our customers may take place on federal land, requiring leases from the federal government to conduct such drilling and completion activities. In some cases, federal agencies have cancelled oil and natural gas leases on federal lands. Consequently,
our operations in certain areas of the country may be interrupted or suspended for varying lengths of time, causing a loss of revenue and potentially having a materially adverse effect on our operations. Any such changes could have a material
adverse effect on our financial condition and results of operations.
We are subject to the trucking safety regulations, which are
likely to be amended, and made stricter, as part of the initiative known as Compliance, Safety, Accountability, or CSA. If our current USDOT safety rating of Satisfactory is downgraded in connection with this initiative, our
business and results of our operations may be adversely affected.
As part of the CSA initiative, the FMCSA is
expected to open a rulemaking docket in 2012 (originally expected in 2011) for purposes of changing its safety rating methodology. Any new methodology adopted in the rulemaking is likely to link safety ratings more closely to roadside inspection and
driver violation data gathered and analyzed from month to month under the FMCSAs new Safety Measurement System, or SMS. This linkage could result in greater variability in safety ratings than the current system, in which a safety
rating is based on relatively infrequent on-site compliance audits at a carriers places of business. Preliminary studies by transportation consulting firms indicate that Satisfactory ratings (or any equivalent under a new SMS-based
system) may become more difficult to achieve and maintain under such a system. If our operations lose their current Satisfactory rating, which is the highest and best rating under this initiative, we may lose some of our customer
contracts that require such a rating, adversely affecting our business prospects and results of operations.
Item 1B.
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Unresolved Staff Comments
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None.
We lease our
corporate headquarters offices in Scottsdale, Arizona and we own or lease numerous facilities including administrative offices, sales offices, truck yards, maintenance facilities, warehouses and well disposal sites in 35 states. We also own or lease
46 salt water disposal wells or underground injection wells in Texas, Ohio, Mississippi, North Dakota and Montana as of December 31, 2012. For the year ended December 31, 2012, the total rent expense associated with our leased properties, other
than salt water disposal wells, was approximately $2.6 million. We believe that we have satisfactory title to the properties owned and used in our businesses, subject to liens for taxes not yet payable, liens incident to minor encumbrances, liens
for credit arrangements (including liens under the Amended Credit Facility) and easements and restrictions that do not materially detract from the value of these properties, our interests in these properties, or the use of these properties in our
businesses.
We believe all properties that we currently occupy are suitable for their intended uses. We believe that we have
sufficient facilities to conduct our operations. However, we continue to evaluate the purchase or lease of additional properties or the consolidation of our properties, as our business requires.
25
Item 3.
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Legal Proceedings
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We are
party to legal proceedings and potential claims arising in the ordinary course of our business, including claims related to employment matters, contractual disputes, personal injuries and property damage. In addition, various legal actions, claims
and governmental inquiries and proceedings are pending or may be instituted or asserted in the future against us and our subsidiaries. See Litigation in Note 13, Commitments and Contingencies, of the Notes to our Consolidated
Financial Statements herein for a description of our legal proceedings.
Item 4.
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Mine Safety Disclosures
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N/A
26
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1)
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Organization and Nature of Business Operations
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Description of Business
Heckmann Corporation, a Delaware Corporation, together with its subsidiaries (collectively, the Company, we, us or our), which prior to the Companys
acquisition of TFI Holdings Inc. and Thermo Fluids Inc. (collectively, TFI) on April 10, 2012 (the TFI Acquisition) was solely focused on total water solutions for shale or unconventional oil and gas
exploration.
Since the closing of the TFI Acquisition on April 10, 2012, the Company has operated through two business
segments: its Fluids Management Division (formerly Heckmann Water Resources or HWR): and its Recycling Division (formerly Heckmann Environmental Services or HES), which includes TFI. Fluids Management addresses the pervasive demand for diverse water
solutions required for the production of oil and gas in an integrated and efficient manner through various service and product offerings. Fluid Managements services include water delivery and disposal, trucking, fluids handling, treatment and
temporary and permanent pipeline facilities, and water infrastructure services for oil and gas exploration and production companies. Fluids Management also transports fresh water for production and provides services for site preparation, water pit
excavations and remediation.
Fluids Management currently operates multi-modal water disposal, treatment, trucking and
pipeline transportation operations in select shale areas in the United States in the Haynesville, Eagle Ford, Marcellus/Utica, Tuscaloosa Marine, Barnett, Mississipian Lime and Permian Basin Shale areas and since the closing of the merger with Power
Fuels on November 30, 2012 with and into the Companys wholly-owned Rough Rider Acquisition, LLC, subsidiary, the Bakken Share area. Fluids Management serves customers seeking fresh water acquisition, temporary water transmission and
storage, transportation, treatment or disposal of fresh water and complex water flows, such as flowback and produced brine water, in connection with shale oil and gas hydraulic fracturing drilling, or hydrofracturing, operations.
Recycling provides route-based environmental services and waste recycling solutions that focus on the collection and
recycling of used motor oil (UMO) and is the largest seller of reprocessed fuel oil (RFO) from recovered UMO in the Western United States. Historically, Recycling has supplied a large percentage of its RFO for use in the
production of asphalt, and consequently experiences some seasonality in its business. Demand for asphalt and asphalt products are generally higher during the summer months, due to increases in highway traffic and road construction work.
During 2013, the Company intends to commence an internal reorganization with the intention of managing the Companys operations by
end-markets served. If the proposed reorganization were to take place, the Company would likely replace its existing segments, Fluids Management and Recycling, with the following three segments: (i) Oil Shale Solutions; (ii) Gas Shale
Solutions; and (iii) Industrial Recycling Solutions. Further analysis is necessary and a final decision has not yet been made. As described in Note 16, a prospective change to the Companys operating segments, if adopted, would likely
cause the composition of the Companys reportable segments to change.
Basis of Presentation
The accompanying audited consolidated financial statements of the Company have been prepared by management in accordance with the
instructions to Form 10-K of the United States Securities and Exchange Commission (the SEC). These statements include all normal reoccurring adjustments considered necessary by management to present a fair statement of the
consolidated balance sheets, results of operations, and cash flows.
The Companys consolidated financial statements for
the year ended December 31, 2012 include the results of operations of Keystone Vacuum, Inc., Thermo Fluids Inc., Harmony, All Phase, Appalachian Water Services, LLC and Power Fuels from their acquisition dates of February 3,
2012, May 31, 2012, June 15, 2012, September 1, 2012 and November 30, 2012, respectively. The Companys consolidated financial statements for the years ended December 31, 2012 and 2011 include the results
of operations of Bear Creek, LLC, Devonian Industries, Inc., Sand Hill Foundation, LLC, Excalibur Energy Services, Inc., Blackhawk, LLC and Consolidated Petroleum, Inc. from their acquisition dates of April 1, 2011, April 4,
2011, April 12, 2011, May 5 2011 and June 14, 2011, respectively. The business comprising the Companys former bottled water segment is presented as discontinued operations in the Companys consolidated financial
statements. See Note 18Discontinued Operations for additional information. Unless stated otherwise, any reference to income statement items in these accompanying audited consolidated financial statements refers to results from
continuing operations.
F-12
Use of Estimates
The Companys consolidated financial statements have been prepared in conformity with generally accepted accounting principles in the
United States (U.S. GAAP). The preparation of the financial statements requires management to make estimates and judgments that affect the reported amounts of assets and liabilities and the disclosure of contingencies at the date of
the financial statements, as well as the reported amounts of revenues and expenses during the reporting period. Estimates have been prepared on the basis of the most current and best available information, however actual results could differ
from those estimates.
(2)
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Summary of Significant Accounting Policies
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Principles of Consolidation
The consolidated financial statements include the accounts of the Company and its subsidiaries. All intercompany accounts, transactions and profits are eliminated in consolidation.
Cash Equivalents
The Company considers all highly liquid investments with original maturities of three months or less when purchased to be cash equivalents. The Company maintains bank accounts in the United States. A
majority of funds considered cash equivalents are invested in institutional money market funds. The Company has not experienced any historical losses in such accounts and believes that the risk of any loss is minimal.
Restricted Cash
In connection with the Power Fuels merger (see Note 3) assets received in exchange for the merger consideration excluded accounts receivable greater than ninety days as of November 30, 2012.
Subsequent collections on these accounts receivable by the Company are required to be remitted to the former sole owner of Power Fuels. As of December 31, 2012, the Company collected $3.5 million of accounts receivable, which were greater than
ninety days at November 30, 2012. Cash collected on these accounts receivable is classified as restricted cash and the corresponding liability due to the former owner is classified as a component of other accrued expenses at December 31,
2012.
Marketable Securities
The Companys investments in marketable debt and equity securities are classified and accounted for as available-for-sale. The Company may or may not hold securities until maturity. As these debt and
equity securities are viewed by the Company as available to support current operations they are classified as current assets in the consolidated balance sheet including those with maturities greater than twelve months. These marketable securities
are carried at fair value with any unrealized gains or losses recorded in accumulated other comprehensive income (loss), a component of equity, until realized. Realized gains and losses are calculated based on specific identification to the
individual securities involved with the resulting gains and losses included in other (expense) income in the consolidated statements of operations. The carrying value of marketable securities was $5.2 million at December 31, 2011. There were no
marketable securities at December 31, 2012. Refer to Note 5 for additional information.
Other-than-temporary declines in
market value from original cost are recognized as a loss in the current years operations. In determining whether an other-than-temporary decline in market value has occurred, the Company considers the duration and extent to which the fair
value of the investment is below its cost.
Accounts Receivable
Accounts receivable are recognized and carried at the original invoice amount less an allowance for expected uncollectible amounts.
Inherent in the assessment of the allowance for doubtful accounts are certain judgments and estimates including, among others, the customers willingness or ability to pay, the Companys compliance with customer invoicing requirements, the
effect of general economic conditions and the ongoing relationship with the customer. Accounts with outstanding balances longer than the payment terms are considered past due. The Company writes off trade receivables when it determines that they
have become uncollectible. Bad debt expense is reflected as a component of general and administrative expenses in the consolidated statements of operations.
The following table summarizes activity for allowance for doubtful accounts (in 000s):
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2012
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2011
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2010
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Beginning balance at January 1,
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$
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2,636
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$
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1,232
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$
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Bad debt expense
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6,296
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2,206
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94
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Acquisition of CVR
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1,138
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Charge offs, net
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(2,965
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)
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(802
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)
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Ending balance at December 31,
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$
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5,967
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$
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2,636
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$
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1,232
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F-13
Fair Value of Financial Instruments
Fair value is 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 carrying amounts of the Companys cash equivalents, accounts receivable and accounts payable approximate fair value due to the short-term nature of these instruments. The carrying values of the
Companys marketable securities are adjusted to fair value at the end of each reporting period based on quoted market prices. The carrying value of the Companys contingent consideration is adjusted to fair value at the end of each
reporting period using a probability-weighted discounted cash flow model. Refer to Note 9 for disclosures on the fair value of the Companys marketable securities and contingent consideration at December 31, 2012 and 2011.
The Companys 2018 Notes are carried at cost. Their estimated fair values are based on quoted market prices. The fair value of the
Companys Amended Revolving Credit Facility and other debt obligations including capital leases, secured by various properties and equipment, bears interest at rates commensurate with market rates and therefore their respective carrying values
approximate fair value. Refer to Note 8 for disclosures on the fair value disclosure of the Companys debt instruments at December 31, 2012.
Inventories
Inventories consist primarily of salable fuel oil and
antifreeze and are stated at the lower of cost or market.
Property and Equipment
Property and equipment is recorded at cost. Depreciation is recorded using the straight-line method over the estimated useful lives of the
related assets ranging from three to thirty nine years. Leasehold improvements are depreciated over the life of the lease including renewal options that are reasonably assured or the life of the asset, whichever is shorter. The range of useful lives
for the components of property, plant and equipment are as follows:
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Land improvements
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5-20 years
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Buildings
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15-39 years
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Leasehold improvements
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5-20 years
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Pipelines
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10-30 years
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Disposal wells
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3-15 years
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Machinery and equipment
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3-15 years
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Equipment under capital leases
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4-6 years
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Motor vehicles and trailers
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3-10 years
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Rental equipment
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5-15 years
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Office equipment
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3-7 years
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Expenditures for betterments that increase productivity and/or extend the useful life of an asset are
capitalized. Maintenance and repair costs are charged to expense as incurred. Upon disposal, the related cost and accumulated depreciation are removed from their respective accounts, and any gains or losses are included in other (expense) income,
net in the consolidated statements of operations. Depreciation expense was $41.9 million, $21.4 million, and $3.4 million for the years ended December 31, 2012, 2011 and 2010, respectively, and is characterized as a component of cost of sales
in the consolidated statements of operations.
Goodwill
Goodwill represents the excess of the purchase price over the fair value of the net assets of businesses acquired. The Company has made
acquisitions over the years that have resulted in the recognition and accumulation of significant goodwill. The carrying values of goodwill at December 31, 2012 and 2011 were $555.1 million and $90.0 million, respectively. The TFI
acquisition and the merger with Power Fuels accounted for approximately $138.4 million and $312.7 million, respectively, of the increase to goodwill during 2012. Refer to Note 3 for additional information on the TFI acquisition, the merger with
Power Fuels and other 2012 acquisition activity. Goodwill is not amortized. Instead, goodwill is required to be tested for impairment annually and between annual tests if events or circumstances lead to a determination that it is more likely than
not that the fair value of a reporting unit is less than its carrying amount. The goodwill impairment test involves a two-step process; however, if after assessing the totality of events or circumstances, an entity determines it is not more likely
than not that the fair value of a reporting unit is less than its carrying amount, then performing the two-step impairment test is unnecessary.
In the event a determination is made that it is more likely than not that the fair value of a reporting unit is less than its carrying value, the first step of the two-step process must be performed. The
first step of the test, used to identify potential impairment,
F-14
compares the estimated fair value of a reporting unit with its carrying amount, including goodwill. If the fair value of a reporting unit exceeds its carrying amount, goodwill of the reporting
unit is not considered to be impaired and the second step of the impairment test is unnecessary. If the carrying amount of a reporting unit exceeds its fair value, the second step of the impairment test must be performed to measure the amount of the
impairment loss, if any. The second step of the goodwill impairment test compares the implied fair value of reporting unit goodwill with the carrying amount of that goodwill. The implied fair value of goodwill is determined in the same manner as
goodwill recognized in a business combination. If the carrying amount of the reporting unit goodwill exceeds the implied fair value of that goodwill, an impairment loss is recognized in an amount equal to that excess.
An entity has the option to bypass the qualitative assessment for any reporting unit in any period and proceed directly to performing the
first step of the two-step goodwill impairment test. At September 30, 2012, the Company elected to bypass the qualitative assessment and performed step one of the goodwill impairment test for each of its three reporting units: the pipeline
reporting unit, the Recycling Division reporting unit (which is also an operating segment) and the Fluids Management reporting unit (which is also an operating segment) excluding the pipeline operations. Refer to Note 16 for additional information
on the Companys operating segments. The fair values of the reporting units were estimated utilizing a combination of two valuation techniques: the discounted cash flow method (Income Approach) and the market comparable method (Market
Approach). Based on the results of the Companys 2012 third quarter goodwill impairment test, the fair values of the Companys reporting units were determined to exceed their respective carrying amounts and accordingly, the second step of
the impairment test was not necessary. In addition, the Company made a qualitative assessment as of December 31, 2012 and concluded it was not more likely than not any of the reporting units fair values were less than their carrying
values at that time.
Debt Issuance Costs
The Company capitalizes costs associated with the issuance of debt and amortizes them as additional interest expense over the lives of the
respective debt instrument on a straight-line basis, which approximates the effective interest method. The unamortized balance of deferred financing costs was $24.4 million and $2.6 million at December 31, 2012 and 2011, respectively and is
included in other long-term assets in the consolidated balance sheets. Upon the prepayment of related debt, the Company accelerates the recognition of the unamortized cost, which is characterized as loss on extinguishment of debt in the consolidated
statements of operations. During the year ended December 31, 2012 the Company wrote-off the unamortized balance of issuance costs related to its Old Credit Facility in connection with the repayment of the Old Credit Facility and the issuance of
the New Credit Facility. Refer to Note 8 for additional information.
Impairment of Long-Lived Assets and Intangible
Assets with Finite Useful Lives
Long-lived assets including intangible assets with finite useful lives are evaluated
for impairment whenever events or changes in circumstances indicate the carrying value of a long-lived asset (or asset group) may not be recoverable. If an impairment indicator is present, the Company evaluates recoverability by comparing the
estimated future cash flows of the category classes, on an undiscounted basis, to their carrying values. The category class represents the lowest level for which identifiable cash flows are largely independent of the cash flows of other groups of
assets and liabilities. If the undiscounted cash flows exceed the carrying value, the asset group is recoverable and no impairment is present. If the undiscounted cash flows are less than the carrying value, the impairment is measured as the
difference between the carrying value and the fair value of the long-lived asset (or asset group). During the year ended December 31, 2012, the Company recognized a $3.7 million impairment loss on three salt water disposal wells primarily in
the Haynesville shale area. The Company tested the disposal wells for recoverability after the wells developed technical problems which required the Company to suspend their use. The estimated future cash flows used to test the recoverability and
measure the fair values of the disposal wells included an estimate of future expenditures necessary to identify the source of the problems and to take corrective action to restore the wells functionality or convert them to an alternate use.
During the year ended December 31, 2012, the Company also recognized a $2.4 million impairment loss related to the write-down of a customer relationship intangible associated with a portion of a prior business acquisition. The impairment loss
was recognized in the Companys Fluids Management segment and was triggered by the Companys updated assessment of the reduced growth prospects of the business and the related impact on its expected financial performance. During the years
ended December 31, 2011 and 2010, the Company concluded impairment indicators were not present and thus no impairments were noted to test the assets for recoverability during those years.
Revenue Recognition
The Company recognizes revenues in accordance with Accounting Standards Codification 605
(ASC 605 Revenue Recognition)
and Staff Accounting Bulletin No 104, and accordingly all of the
following criteria must be met for revenues to be recognized: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the price to the buyer is fixed and determinable and collectibility is reasonably
assured. The majority of the Companys revenue results from contracts with direct customers and revenues are generated upon performance of contracted services.
F-15
The Companys Fluids Management Division derives the majority of its revenue from the
transportation of fresh and salt water by Company-owned trucks or through a temporary or permanent water transport pipeline to customer sites for use in drilling and hydraulic fracturing activities and from customer sites to remove and dispose of
backflow and produced water originating from oil and gas wells. Revenues are also generated through fees charged for use of the Companys disposal wells and from the rental of tanks and other equipment. Certain customers, limited to those under
contract with us to utilize the pipeline, have an obligation to dispose of a minimum quantity (number of barrels) of saltwater over the contract period. Transportation and disposal rates are generally based on a fixed fee per barrel of disposal
water or, in certain circumstances, transportation is based on an hourly rate. Revenue is recognized based on the number of barrels transported or disposed or at hourly rates for transportation. Rates for other services are based on negotiated rates
with the Companys customers and revenue is recognized when the services have been performed.
The Companys
Recycling Division derives the majority of its revenue from the sale of used motor oil and antifreeze after it is refined by one of its processing facilities. Revenue is recognized upon shipment or delivery, dependent on contracted terms, of salable
fuel oil or upon recovery service provided in the receipt of waste oil and antifreeze per specific customer contract terms. Transportation costs charged to customers are included in revenue.
Sales tax amounts collected from customers are recorded on a net basis.
Concentration of Customer Risk
Three of the Companys customers comprised 39% of the Companys consolidated revenues for the year ended December 31, 2012 and 34% of the Companys consolidated accounts receivable at
December 31, 2012 consisted of accounts receivable due from three customers. One of the Companys customers comprised 25% of the Companys consolidated revenues and 29% of the Companys consolidated accounts receivable for the
year ended December 31, 2011. Two of the Companys customers comprised 16% and 12%, respectively, of total consolidated revenues for the year ended December 31, 2010.
Income Taxes
Income taxes are accounted for using the asset and liability method. Under this method, deferred income tax assets and liabilities are recognized for the expected future tax consequences attributable to
temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases including temporary differences related to assets acquired in business combinations (Note 3). Deferred tax
assets are also recognized for net operating loss, capital loss and tax credit carryforwards. Deferred income tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the related
temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. A valuation allowance is provided for
those deferred tax assets for which realization of the related benefits is not more likely than not.
The Company measures and
records tax contingency accruals in accordance with accounting principles generally accepted in the United States (GAAP) which prescribes a threshold for the financial statement recognition and measurement of a tax position taken or
expected to be taken in a return. Only positions meeting the more likely than not recognition threshold may be recognized or continue to be recognized. A tax position is measured at the largest amount that is greater than 50 percent
likely of being realized upon ultimate settlement. The Companys policy is to recognize interest and penalties accrued on any unrecognized tax benefits as a component of income tax expense.
Share-Based Compensation
Share-based compensation for all share-based payment awards granted is based on the grant-date fair value. Generally, awards of stock options granted to employees vest in equal increments over a
three-year service period from the date of grant and awards of restricted stock vest over a two or three year service period from the date of grant . The grant date fair value of the award is recognized to expense on a straight-line basis over the
service period for the entire award, that is, over the requisite service period of the last separately vesting portion of the award. As of December 31, 2012 there was $4.3 million of unrecognized compensation cost related to unvested stock
options, which are expected to vest over a weighted average period of approximately of 1.1 years. As of December 31, 2012 there was $2.9 million of unrecognized compensation cost related to unvested shares of restricted stock, which are
expected to vest over a weighted average period of approximately 1.5 years. Refer to Note 11 for further discussion.
Recent Accounting Pronouncements
In February 2013, the Financial Accounting Standards Board (the FASB) issued Accounting Standards Update (ASU) No. 2013-02,
Reporting of Amounts Reclassified out of
Accumulated Other Comprehensive Income
(ASU 2013-02). The amendments in this update do not change the current requirements for reporting net income or other comprehensive income in financial statements.
F-16
However, the amendments require an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to
present, either on the face of the statement where net income is presented or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified
is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to
cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. The amendments in this update are effective prospectively for reporting periods beginning after December 15, 2012, which for the
Company is the reporting period starting January 1, 2013. The Company does not anticipate the adoption of ASU 2013-02 will have a material impact on the Companys consolidated financial statements. As permitted under ASU 2013-02, the
Company has elected to present reclassification adjustments from each component of accumulated other comprehensive income within a single note to the financial statements beginning in the first quarter of 2013, if applicable.
In July 2012, the FASB issued ASU No. 2012-02,
Testing Indefinite-Lived Intangible Assets for Impairment
(ASU
2012-02). The amendments in this update provide an entity the option to first assess qualitative factors to determine whether the existence of events and circumstances indicates that it is more likely than not that the indefinite-lived
intangible asset is impaired. If, after assessing the totality of events and circumstances, an entity concludes that it is not more likely than not that the indefinite lived intangible asset is impaired, then the entity is not required to take
further action. However, if an entity concludes otherwise, then it is required to determine the fair value of the indefinite-lived intangible asset and perform the quantitative impairment test by comparing the fair value with the carrying amount in
accordance with Accounting Standards Codification subtopic 350-30,
General Intangibles other than Goodwill
. An entity also has the option to bypass the qualitative assessment for any indefinite-lived intangible asset in any period and proceed
directly to performing the quantitative impairment test. An entity will be able to resume performing the qualitative assessment in any subsequent period. The amendments in this update are effective for annual and interim impairment tests performed
for fiscal years beginning after September 15, 2012, which for the Company are the annual and interim periods starting January 1, 2013. As of December 31, 2012, the Company did not have any intangible assets with indefinite lives. At
this time, the Company does not anticipate the adoption of ASU 2012-02 will have a material impact on the Companys consolidated financial statements.
In September 2011, the FASB issued ASU No. 2011-08,
Testing Goodwill for Impairment
(ASU 2011-08). The amendments in this update provide an entity the option to first assess
qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of
events or circumstances, an entity determines it is not more likely than not that the fair value of the reporting unit is less than its carrying amount, then performing the two-step impairment test is unnecessary. However, if an entity concludes
otherwise, then it is required to perform the first step of the two-step impairment test by calculating the fair value of the reporting unit and comparing the fair value with the carrying amount of the reporting unit. The amendment does not change
the requirement to perform the second step of the interim goodwill impairment test to measure the amount of an impairment loss, if any, if the carrying amount of a reporting unit exceeds its fair value. Under the amendments in this update, an entity
has the option to bypass the qualitative assessment for any reporting unit in any period and proceed directly to performing the first step of the two-step goodwill impairment test. An entity may resume performing the qualitative assessment in any
subsequent period. The amendments in this update were effective for annual and interim goodwill impairment tests performed for fiscal years beginning after December 15, 2011, which for the Company were the annual and interim periods starting
January 1, 2012. As permitted under ASU 2011-08 the Company elected to bypass the qualitative assessment at September 30, 2012, which was the date the Company performed its annual test, and instead proceeded directly to performing the
first step of the two-step goodwill impairment test. Refer to the goodwill discussion in the significant accounting policies section of Note 2 for additional information.
(3)
|
Business Acquisitions
|
Power Fuels Merger
On November 30, 2012, the Company and its wholly-owned subsidiary, Rough Rider Acquisition, LLC completed a merger with Power Fuels of which the Companys Chief Executive Officer and Vice
Chairman, Mark D. Johnsrud, was the sole member. Prior to the merger, Power Fuels was a privately held North Dakota-based environmental solutions company providing delivery and disposal of environmental products, fluids transportation and handling,
water sales, and equipment rental services for unconventional oil and gas exploration and production businesses. As a result of the Power Fuels Merger on November 30, 2012, Power Fuels and its subsidiaries became wholly-owned subsidiaries of
the Company.
The Merger consideration consisted of the following:
|
|
|
95.0 million unregistered shares of the Companys common stock, with a fair value of approximately $371.5 million, of which 10.0 million
shares were placed into escrow for up to three years to pay certain potential indemnity claims; and
|
F-17
|
|
|
$129.4 million in cash including adjustment for targeted versus actual debt.
|
In connection with the Power Fuels merger, the Company incurred transaction costs of approximately $5.1 million, which are reported in
selling, general and administrative expenses in the accompanying consolidated statements of operations for the year ended December 31, 2012.
The Power Fuels merger has been accounted for as a business combination under the acquisition method of accounting. The amounts recognized for property, plant and equipment and customer relationships are
provisional and adjustments may occur based upon the final valuation of these items. The Company expects to finalize these amounts no later than one year from the acquisition date.
The preliminary allocation of the aggregate purchase price at November 30, 2012 is summarized as follows (in 000s):
|
|
|
|
|
|
|
November 30,
2012
|
|
Cash
|
|
$
|
2,111
|
|
Accounts receivable
|
|
|
57,405
|
|
Inventory
|
|
|
3,443
|
|
Other assets
|
|
|
2,552
|
|
Customer relationships
|
|
|
145,000
|
|
Property, plant and equipment
|
|
|
278,527
|
|
Goodwill
|
|
|
312,715
|
|
Accounts payable and accrued expenses
|
|
|
(24,027
|
)
|
Debt
|
|
|
(150,367
|
)
|
Deferred income tax liabilities, net
|
|
|
(126,503
|
)
|
|
|
|
|
|
Total
|
|
$
|
500,856
|
|
|
|
|
|
|
The purchase price allocation requires subjective estimates that, if incorrect, could be material to the
Companys consolidated financial statements including the amount of depreciation and amortization expense. The most important estimates for measurement of tangible fixed assets are (a) the cost to replace the asset with a new asset and
(b) the economic useful life of the asset after giving effect to its age, quality and condition. The most important estimates for measurement of intangible assets are (a) discount rates and (b) timing and amount of cash flows
including estimates regarding customer renewals and cancelations.
The goodwill recognized is attributable to the premium
associated with the immediate entry into the oil-rich Bakken Shale area by leveraging Power Fuels assembled workforce and established operations.
TFI Acquisition
On April 10, 2012, the Company completed the
acquisition (the TFI Acquisition) of all the issued and outstanding shares of TFI Holdings, Inc. and its wholly-owned subsidiary, Thermo Fluids Inc. (collectively, TFI), a route-based environmental services and waste
recycling solutions provider that focuses on the collection and recycling of UMO and the sale of RFO from recovered UMO.
The
aggregate purchase price of $245.4 million was comprised of approximately $229.6 million in cash, and 4,050,926 shares of the Companys common stock with a fair value of approximately $15.8 million, which shares were issued in a private
placement and are held in escrow in respect of indemnification obligations of the sellers of TFI through the earlier of (i) 30 days after the provision of audited financial statements of TFI for the year ended December 31, 2012 and
(ii) April 15, 2013. In conjunction with the TFI Acquisition, the Company incurred transaction costs of approximately $1.6 million, which are reported in selling, general and administrative expenses in the accompanying consolidated
statements of operations for the year ended December 31, 2012.
F-18
The acquisition of TFI has been accounted for as a business combination under the
acquisition method of accounting. The amounts recognized for customer and vendor relationships are provisional and further adjustments may occur as the valuation data and underlying assumptions are subject to further review by the management and the
Companys third party appraisers. The Company expects to finalize these amounts no later than one year from the acquisition date.
The allocation of the aggregate purchase price at April 10, 2012 is summarized as follows (in 000s):
|
|
|
|
|
|
|
April 10,
2012
|
|
Accounts receivable
|
|
$
|
13,808
|
|
Inventory
|
|
|
3,456
|
|
Other assets
|
|
|
1,431
|
|
Customer relationships
|
|
|
101,300
|
|
Vendor relationships
|
|
|
16,300
|
|
Other intangibles
|
|
|
1,400
|
|
Property, plant and equipment
|
|
|
25,194
|
|
Goodwill
|
|
|
138,446
|
|
Accounts payable and accrued expenses
|
|
|
(13,045
|
)
|
Deferred income tax liabilities, net
|
|
|
(42,886
|
)
|
|
|
|
|
|
Total
|
|
$
|
245,404
|
|
|
|
|
|
|
The goodwill recognized is attributable to TFIs assembled workforce and the premium associated with
the opportunity to further diversify the Companys operations and service offerings.
Other Acquisitions
During the year ended December 31, 2012, the Company completed four other acquisitions, including three in Fluids
Management (one in each of the first, second and third quarters of 2012) and one in Recycling in the second quarter of 2012. The aggregate purchase price of the acquired businesses was approximately $38.9 million consisting of 7,589,164 shares of
the Companys common stock with an estimated fair value of approximately $30.5 million, cash consideration of approximately $2.6 million and approximately $5.8 million of contingent consideration. In conjunction with these acquisitions we
incurred transaction costs of approximately $1.0 million, which are reported in general and administrative expenses in the accompanying consolidated statements of operations. The results of operations of the four acquisitions were not material to
our consolidated results of operations.
In conjunction with the acquisition completed by Fluids Management in the third
quarter of 2012, the Company acquired a 51% interest in a business and has a call option to buy the remaining 49% at a fixed price at a stated future date, and the noncontrolling interest holder has a put option to sell the remaining 49% percent to
the Company under those same terms. As such, the fixed price of the call option is equal to the fixed price of the put option. In accordance with Accounting Standards Codification 480
(ASC 480 Distinguishing Liabilities from
Equity)
, the option contracts are viewed on a combined basis with the noncontrolling interest and accounted for as the Companys financing of the purchase of the noncontrolling interest. Accordingly the present value of the option was
$9.0 million and was classified as other long-term obligations in the Companys consolidated balance sheet at December 31, 2012 with the financing accreted, as interest expense, to the strike price of the option over the period until
settlement.
The allocations of the combined aggregate purchase prices at the respective acquisition dates are summarized as
follows (in 000s):
|
|
|
|
|
|
|
Various Dates,
2012
|
|
Accounts receivable
|
|
$
|
2,653
|
|
Equipment
|
|
|
21,546
|
|
Customer relationships
|
|
|
10,164
|
|
Goodwill
|
|
|
13,922
|
|
Other long-term obligations
|
|
|
(8,769
|
)
|
Other liabilities
|
|
|
(613
|
)
|
|
|
|
|
|
Total
|
|
$
|
38,903
|
|
|
|
|
|
|
Pro forma Financial Information Reflecting the Power Fuels, TFI and Other Acquisitions
The following unaudited pro forma results of operations for the years ended December 31, 2012 and 2011, respectively, assumes that
all of the acquisitions were completed at the beginning of the periods presented. The pro forma results include adjustments to reflect additional amortization of intangibles and depreciation of assets associated with the acquired and merged
businesses and additional interest expense for debt issued to consummate these transactions.
F-19
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2012
|
|
|
2011
|
|
Pro forma revenues
|
|
$
|
750,817
|
|
|
$
|
568,916
|
|
Pro forma net income from continuing operations
|
|
|
34,142
|
|
|
|
18,587
|
|
Pro forma net income per share from continuing operations:
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
0.14
|
|
|
$
|
0.08
|
|
Diluted
|
|
|
0.13
|
|
|
|
0.08
|
|
The pro forma financial information presented above is not necessarily indicative of either the results
of operations that would have occurred had the acquisitions been effective as of January 1 of the respective years, or of future operations of the Company.
Basic and diluted loss per common share from continuing operations, per common share from discontinued operations and
net loss per common share have been computed using the weighted average number of shares of common stock outstanding during the period. Basic earnings per share (EPS) excludes dilution and is computed by dividing net income (loss)
applicable to common stockholders by the weighted average number of common shares outstanding for the period. Diluted EPS is based upon the weighted average number of common shares outstanding during the period plus the additional weighted average
common equivalent shares during the period. Common equivalent shares result from the assumed exercises of outstanding warrants, restricted stock and stock options, the proceeds of which are then assumed to have been used to repurchase outstanding
shares of common stock. Inherently, stock warrants are deemed to be anti-dilutive when the average market price of the common stock during the period is less than the exercise prices of the stock warrants.
The following table presents the calculation of basic and diluted net loss per common share (in 000s except per share data):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2012
|
|
|
2011
|
|
|
2010
|
|
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
Income loss from continuing operations
|
|
$
|
2,527
|
|
|
$
|
(108
|
)
|
|
$
|
(10,300
|
)
|
Loss from discontinued operations
|
|
|
|
|
|
|
(22,898
|
)
|
|
|
(4,393
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to common stockholders
|
|
$
|
2,527
|
|
|
$
|
(23,006
|
)
|
|
$
|
(14,693
|
)
|
Plus: income impact of assumed conversion of AWS call option
|
|
|
336
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to common stockholders plus assumed conversions
|
|
|
2,863
|
|
|
|
(23,006
|
)
|
|
|
(14,693
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares basic
|
|
|
149,940,096
|
|
|
|
114,574,730
|
|
|
|
108,819,384
|
|
Dilutive effect of contingently issuable shares
|
|
|
7,401,795
|
|
|
|
|
|
|
|
|
|
Dilutive effect of stock warrants
|
|
|
117,757
|
|
|
|
|
|
|
|
|
|
Dilutive effect of stock-based awards
|
|
|
98,235
|
|
|
|
|
|
|
|
|
|
Dilutive effect of AWS call option
|
|
|
886,159
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total weighted average shares diluted
|
|
|
158,444,042
|
|
|
|
114,574,730
|
|
|
|
108,819,384
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) per common share from continuing operations basic (a)
|
|
$
|
0.02
|
|
|
$
|
|
*
|
|
$
|
(0.09
|
)
|
Income (loss) per common share from continuing operations diluted (a)
|
|
|
0.02
|
|
|
|
|
*
|
|
|
(0.09
|
)
|
Loss per common share from discontinued operations basic and diluted
|
|
|
|
|
|
|
(0.20
|
)
|
|
|
(0.05
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) per common share
|
|
$
|
0.02
|
|
|
$
|
(0.20
|
)
|
|
$
|
(0.14
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Antidilutive stock-based awards and warrants excluded (b)
|
|
|
3,156,191
|
|
|
|
35,960,40
|
|
|
|
66,687,857
|
|
(a)
|
Net income (loss) per common share from continuing operations was less than $0.01 for the year ended December 31, 2011.
|
(b)
|
Antidilutive stock-based awards and warrants consist of those instruments with an exercise price in excess of the average market price of the Companys common
stock for the applicable reporting period. The decrease in antidilutive shares is due primarily to the expiration of the Public Warrants and the Sponsors Warrants in November 2011, as described in Note 10.
|
F-20
There were no available-for-sale securities as of December 31, 2012. The amortized cost, gross unrealized holding
gains and losses and fair value of available-for-sale securities as of December 31, 2011 was as follows (in 000s):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contractual
Maturity
(in years)
|
|
|
Amortized
Cost
|
|
|
Gross Unrealized Holding
|
|
|
Fair
Value
|
|
|
|
|
|
Gains
|
|
|
Losses
|
|
|
December 31, 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Available-for-sale:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate Notes
|
|
|
1
|
|
|
$
|
5,161
|
|
|
$
|
8
|
|
|
$
|
|
|
|
$
|
5,169
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(6)
|
Property, Plant and Equipment, net
|
Property, plant and equipment consists of the following (in 000s):
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2012
|
|
|
2011
|
|
Land
|
|
$
|
10,489
|
|
|
$
|
2,254
|
|
Land improvements
|
|
|
1,060
|
|
|
|
|
|
Buildings and leasehold improvements
|
|
|
36,104
|
|
|
|
5,592
|
|
Pipelines
|
|
|
76,667
|
|
|
|
67,068
|
|
Disposal wells
|
|
|
79,344
|
|
|
|
48,121
|
|
Machinery and equipment
|
|
|
107,151
|
|
|
|
12,793
|
|
Equipment under capital leases
|
|
|
20,771
|
|
|
|
|
|
Motor vehicles and trailers
|
|
|
154,529
|
|
|
|
88,598
|
|
Rental equipment
|
|
|
137,084
|
|
|
|
36,669
|
|
Office equipment
|
|
|
4,540
|
|
|
|
1,191
|
|
|
|
|
|
|
|
|
|
|
|
|
|
627,739
|
|
|
|
262,286
|
|
Less accumulated depreciation
|
|
|
(63,064
|
)
|
|
|
(25,128
|
)
|
Construction in process
|
|
|
40,195
|
|
|
|
32,896
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
$
|
604,870
|
|
|
$
|
270,054
|
|
|
|
|
|
|
|
|
|
|
Depreciation expense for the years ended December 31, 2012, 2011 and 2010 was $42.0 million, $21.4
million and $3.4 million, respectively.
(7)
|
Goodwill and Intangible Assets
|
Goodwill
The change in the carrying amount of goodwill is as follows (in 000s):
|
|
|
|
|
Balance at December 31, 2010
|
|
$
|
41,008
|
|
Additions
|
|
|
50,289
|
|
Other adjustments
|
|
|
(1,289
|
)
|
|
|
|
|
|
Balance at December 31, 2011
|
|
|
90,008
|
|
Additions - TFI Acquisition
|
|
|
138,446
|
|
Additions Power Fuels merger
|
|
|
312,715
|
|
Additions Other acquisitions
|
|
|
13,922
|
|
|
|
|
|
|
Balance at December 31, 2012
|
|
$
|
555,091
|
|
|
|
|
|
|
F-21
Intangible Assets
Intangible assets consist of the following (in 000s):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2012
|
|
|
December 31, 2011
|
|
|
|
Gross
carrying
amount
|
|
|
Accumulated
amortization
|
|
|
Net
|
|
|
Remaining
useful life
(a)
|
|
|
Gross
carrying
amount
|
|
|
Accumulated
amortization
|
|
|
Net
|
|
|
Remaining
useful life
(a)
|
|
Customer relationships (b)
|
|
$
|
268,859
|
|
|
$
|
(15,370
|
)
|
|
$
|
253,489
|
|
|
|
12.3
|
|
|
$
|
14,767
|
|
|
$
|
(2,994
|
)
|
|
$
|
11,773
|
|
|
|
6.1
|
|
Disposal permits
|
|
|
2,788
|
|
|
|
(472
|
)
|
|
|
2,316
|
|
|
|
8.3
|
|
|
|
2,585
|
|
|
|
(180
|
)
|
|
|
2,405
|
|
|
|
8.3
|
|
Customer contracts
|
|
|
17,352
|
|
|
|
(3,073
|
)
|
|
|
14,279
|
|
|
|
14.0
|
|
|
|
17,352
|
|
|
|
(2,041
|
)
|
|
|
15,311
|
|
|
|
15.0
|
|
Vendor relationships
|
|
|
16,300
|
|
|
|
(2,444
|
)
|
|
|
13,856
|
|
|
|
5.0
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other
|
|
|
1,195
|
|
|
|
(437
|
)
|
|
|
758
|
|
|
|
2.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
306,494
|
|
|
$
|
(21,796
|
)
|
|
$
|
284,698
|
|
|
|
12.1
|
|
|
$
|
34,704
|
|
|
$
|
(5,215
|
)
|
|
$
|
29,489
|
|
|
|
11.0
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a)
|
Remaining useful life is weighted average, calculated based on the net book value and the remaining amortization period of each respective intangible asset.
|
(b)
|
During 2012, the Company recognized an impairment charge of $2.4 million for a customer relationship intangible associated with a construction business that was a part
of a prior business acquisition. During 2012, the Company received information from its primary customer in that market that future construction contracts would be directed to competitors whose core competency is construction.
|
Amortization expense was $16.6 million, $3.9 million and $1.2 million for the years ended December 31,
2012, 2011 and 2010, respectively.
As of December 31, 2012, future amortization expense for the other intangible assets
is estimated to be (in 000s):
|
|
|
|
|
2013
|
|
$
|
36,384
|
|
2014
|
|
|
32,500
|
|
2015
|
|
|
29,937
|
|
2016
|
|
|
26,189
|
|
2017
|
|
|
22,309
|
|
Thereafter
|
|
|
137,379
|
|
|
|
|
|
|
Total
|
|
$
|
284,698
|
|
|
|
|
|
|
Debt consists of the following (in 000s) at:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest
Rate
|
|
|
Maturity Date
|
|
December 31,
2012
|
|
|
December 31,
2011
|
|
|
|
|
Unamortized
Deferred
Financing Costs
|
|
|
Debt
|
|
|
Debt
|
|
Amended Revolving Credit Facility(a)
|
|
|
4.11
|
%
|
|
Nov. 2017
|
|
$
|
7,606
|
|
|
$
|
146,990
|
|
|
$
|
|
|
Original Revolving Credit Facility
|
|
|
n/a
|
|
|
(b)
|
|
|
|
|
|
|
|
|
|
|
72,799
|
|
2018 Notes(c)
|
|
|
9.875
|
%
|
|
Apr. 2018
|
|
|
16,802
|
|
|
|
400,000
|
|
|
|
|
|
Term Loan Facility
|
|
|
n/a
|
|
|
(b)
|
|
|
|
|
|
|
|
|
|
|
67,375
|
|
Vehicle Financings payable(d)
|
|
|
3.30
|
%
|
|
Various
|
|
|
|
|
|
|
20,047
|
|
|
|
3,896
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total debt
|
|
|
|
|
|
|
|
$
|
24,408
|
|
|
|
567,037
|
|
|
|
144,070
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Original issue discount(e)
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,277
|
)
|
|
|
|
|
Original issue premium(e)
|
|
|
|
|
|
|
|
|
|
|
|
|
366
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total debt, net
|
|
|
|
|
|
|
|
|
|
|
|
|
566,126
|
|
|
|
144,070
|
|
Less: current portion
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,699
|
)
|
|
|
(11,914
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total long-term debt
|
|
|
|
|
|
|
|
|
|
|
|
$
|
561,427
|
|
|
$
|
132,156
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a)
|
The interest rate presented represents the interest rate on the Amended Revolving Credit Facility at December 31, 2012 excluding the interest rate applicable to
swingline advances outstanding at December 31, 2012.
|
F-22
(b)
|
In April 2012, the Company repaid the outstanding balance of the Original Revolving Credit Facility and the Term Loan Facility with proceeds received in connection with
the issuance of $250.0 million aggregate principal amount of 9.875% senior unsecured notes due 2018.
|
(c)
|
The interest rate presented represents the coupon rate on the 2018 Notes excluding the effect of deferred financing costs, original issue discounts and original issue
premiums. Including the effect of deferred financing costs, original issue discounts and original issue premiums, the effective interest rate on the 2018 Notes is approximately 11.0%.
|
(d)
|
Vehicle financings consist of installment notes payable and capital lease arrangements with a weighted-average annual interest rate of approximately 3.30% and which
mature in varying installments between 2013 and 2017. Installment notes payable and capital lease obligations were $2.1 million and $17.9 million, respectively at December 31, 2012.
|
(e)
|
The original issue discount represents the unamortized difference between the $250.0 million aggregate principal amount of the 2018 Notes issued in April 2012 and the
proceeds received upon issuance (excluding interest and fees). The original issue premium represents the unamortized difference between the proceeds received in connection with the November 2012 issuance of the 2018 Notes (excluding interest and
fees) and the $150.0 million aggregate principal amount thereunder.
|
The required principal payments for all
borrowings for each of the five years following the balance sheet date are as follows (in 000s):
|
|
|
|
|
2013
|
|
$
|
4,699
|
|
2014
|
|
|
4,589
|
|
2015
|
|
|
4,047
|
|
2016
|
|
|
3,363
|
|
2017
|
|
|
150,339
|
|
Thereafter
|
|
|
400,000
|
|
|
|
|
|
|
Total
|
|
$
|
567,037
|
|
|
|
|
|
|
F-23
As of December 31, 2012 the estimated fair value of the Companys debt was as
follows (in 000s):
|
|
|
|
|
|
|
Fair Value
|
|
Amended Revolving Credit Facility
|
|
$
|
146,990
|
|
2018 Notes
|
|
|
413,000
|
|
Capitalized lease obligations
|
|
|
20,047
|
|
|
|
|
|
|
Total
|
|
$
|
580,037
|
|
|
|
|
|
|
On September 7, 2011, the Company entered into a $160.0 million senior secured credit agreement (the
Old Credit Facility), comprised of a $70.0 million term loan facility (the Term Loan) and a $90.0 million revolving credit facility (the Original Revolving Credit Facility), with Regions Bank, as collateral agent,
RBS Citizens Bank, N.A. and First National Bank of Pennsylvania, as co-syndication agents, and the lenders party thereto. The Term Loan and the Original Revolving Credit Facility were scheduled to mature on September 7, 2015. The outstanding
principal balances on the Term Loan and the Original Revolving Credit Facility were $67.4 million and $72.8 million, respectively at December 31, 2011.
On April 10, 2012, the Company completed a private placement offering of $250.0 million aggregate principal amount of 9.875% senior unsecured notes due April 2018 (the Notes). Net
proceeds from the issuance of the Notes, after deducting underwriters fees and offering expenses, totaled $240.8 million and were used to repay the outstanding principal balances of the Old Credit Facility and to partially finance the
acquisition of TFI. In connection with the repayment of the Old Credit Facility, the Company wrote-off approximately $2.6 million of unamortized deferred financing costs associated with the Old Credit Facility, which is characterized as loss on
extinguishment of debt in the Companys consolidated statement of operations for the year ended December 31, 2012.
Concurrent with the April 10, 2012 repayment and termination of the Old Credit Facility, the Company entered into a new $150.0 million senior revolving credit agreement (the New Revolving
Credit Facility) with Wells Fargo Bank as Administrative Agent and the lenders party thereto. The New Revolving Credit Facility contained an uncommitted accordion feature, which allowed the Company to increase borrowings by up to
an additional $100.0 million. On November 30, 2012, the Company amended the senior revolving credit agreement (the Amended Revolving Credit Facility) to increase the commitment from $150.0 million to $325.0 million and extend the
maturity from April 10, 2017 to November 30, 2017. Together with the $100.0 million uncommitted accordion feature under the agreement (which was not affected by the amendment), the Amended Revolving Credit Facility provides for
total maximum potential borrowings of $425.0 million. Interest on the Amended Revolving Credit Facility accrues based generally on London inter-bank offered rate (LIBOR) plus a margin of between 2.50% and 3.75% based on a ratio of the
Companys total debt to EBITDA, or an alternate interest rate equal to the higher of the Federal Funds Rate as published by the Federal Reserve Bank of New York plus
1
/
2
of 1.00%, the prime commercial lending rate of the administrative agent under the Credit Agreement, and monthly LIBOR plus 1.00%, plus a margin of between 1.50% and 2.75% based on the Companys
total debt to EBITDA. As of December 31, 2012, the Company had $177.0 million available for borrowing under the Amended Revolving Credit Facility. A portion of the Amended Revolving Credit Facility is available for the issuance of letters of
credit up to $20.0 million in the aggregate and swingline loans, which are three day loans that can be drawn on the same day as requested for an amount not to exceed $30.0 million. The Company is required to pay fees on the unused commitments of the
lenders under the Amended Revolving Credit Facility, a letter of credit fee on the outstanding stated amount of letters of credit plus facing fees for the letter of credit issuing banks and any other customary fees.
The Companys obligations under the New Revolving Credit Facility are secured by all of the Companys present and future
material property and assets, real and personal (with the exception of certain specified equipment), as well as a pledge of all of the capital stock or ownership interests in the Companys current and future domestic subsidiaries and up to 65%
of the equity interests in our non-U.S. subsidiaries. The terms of the amended senior revolving credit agreement require the Company to comply, on a quarterly basis, with certain financial covenants, including a maximum total debt leverage ratio, a
maximum senior secured debt leverage ratio and a minimum interest coverage ratio. The Companys maximum permitted total debt leverage ratio as of December 31, 2012 is 4.00 to 1.00 through and including March 31, 2014 declining to 3.75 to
1.00 for each fiscal quarter ending thereafter and is calculated as the ratio of consolidated total debt to consolidated EBITDA for the four consecutive fiscal quarters ending on such date as defined by the amended senior revolving credit agreement.
The Companys maximum permitted senior secured debt leverage ratio as of December 31, 2012 and for each fiscal quarter ending thereafter is 2.50 to 1.00 and is calculated as the ratio of consolidated debt (minus unsecured debt) to
consolidated EBITDA for the four consecutive fiscal quarters ending on such date, as defined by the amended senior revolving credit agreement. The Companys minimum permitted interest coverage ratio as of December 31, 2012 and for each
fiscal quarter ending thereafter is 2.75 to 1.00 and is calculated as the ratio of consolidated EBITDA for the four fiscal quarter period then ended, as defined by the amended senior revolving credit agreement, to cash interest expense for the four
consecutive fiscal quarters ending on such date. The Company was in compliance with all applicable debt covenants as of December 31, 2012.
On November 5, 2012, the Company completed a private placement offering of $150.0 million aggregate principal amount of 9.875% senior unsecured notes due April 2018 (the Additional Notes
and with the Notes, are collectively referred to as the 2018 Notes ). Net proceeds from the issuance of the Additional Notes, after deducting underwriters fees and offering expenses, totaled approximately $147.0 million and were
used to partially finance the merger with Power Fuels.
F-24
The 2018 Notes are redeemable, at the Companys option, in whole or in part, at any
time and from time to time on and after April 15, 2015 at the applicable redemption price set forth below, if redeemed during the 12-month period commencing on April 15 of the years set forth below:
|
|
|
|
|
Redemption Period
|
|
Price
|
|
2015
|
|
|
104.938
|
%
|
2016
|
|
|
102.469
|
%
|
2017 and thereafter
|
|
|
100.000
|
%
|
In addition, at any time on or prior to April 15, 2015, the Company may on any one or more occasions
redeem up to 35% of the original aggregate principal amount of the 2018 Notes, with funds in an equal aggregate amount up to the aggregate proceeds of certain equity offerings of the Company, at a redemption price of 109.875%.
The indenture governing the 2018 Notes contains covenants that restrict the Companys ability to take various actions including, but
not limited to, transferring or selling assets, paying dividends, incurring additional indebtedness, issuing preferred stock, and engaging in certain business activities.
Measurements
Fair value is an exit price, representing the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. As such, fair value is a
market-based measurement that should be determined based on assumptions that market participants would use in pricing an asset or liability. U.S. GAAP establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair
value as follows:
|
|
|
Level 1 Observable inputs such as quoted prices in active markets that are accessible at the measurement date for identical assets or
liabilities;
|
|
|
|
Level 2 Inputs, other than the quoted prices in active markets, that are observable either directly or indirectly; and
|
|
|
|
Level 3 Unobservable inputs in which there is little or no market data, which require the reporting entity to develop its own assumptions.
|
Assets and liabilities measured at fair value on a recurring basis as of December 31, 2012 and 2011
and the fair value hierarchy of the valuation techniques the Company utilized to determine such fair value are as follows (in 000s):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value
|
|
|
Quoted Prices in
Active Markets
for Identical
Assets (Level
1)
|
|
|
Significant
Other
Observable
Inputs
(Level 2)
|
|
|
Significant
Unobservable
Inputs (Level 3)
|
|
December 31, 2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contingent consideration
|
|
$
|
10,831
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
10,831
|
|
Obligation for AWS call/put option
|
|
|
9,021
|
|
|
|
|
|
|
|
|
|
|
|
9,021
|
|
|
|
|
|
|
December 31, 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Corporate Notes
|
|
$
|
5,169
|
|
|
$
|
5,169
|
|
|
$
|
|
|
|
$
|
|
|
|
|
|
|
|
Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contingent consideration
|
|
$
|
13,597
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
13,597
|
|
The fair value of the contingent consideration was determined using a probability-weighted income
approach at the acquisition date and is revalued at each reporting date or more frequently if circumstances dictate based on changes in the discount periods and rates, changes in the timing and amount of the revenue estimates and changes in
probability assumptions with respect to the likelihood of achieving the obligations. Contingent consideration reported as current portion of contingent consideration and other long-term obligations in the Companys consolidated balance sheets.
Changes to the fair value of contingent consideration are recorded as other income (expense), net in the Companys consolidated statements of operations. Accretion expense related to the increase in the net present value of the contingent
liabilities is included in interest expense for the period. The fair value measurement is based on significant inputs not observable in the market, which are referred to as Level 3 inputs. The changes to contingent consideration during the years
ended December 31, 2012 and 2011 are as follows (in 000s):
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2012
|
|
|
2011
|
|
Balance at beginning of period
|
|
$
|
13,597
|
|
|
$
|
13,701
|
|
Additions (acquisition-related)
|
|
|
5,845
|
|
|
|
5,000
|
|
F-25
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2012
|
|
|
2011
|
|
Accretion
|
|
|
1,365
|
|
|
|
1,173
|
|
Cash Payments
|
|
|
(1,000
|
)
|
|
|
(500
|
)
|
Stock Payment (Notes 10 and 13 )
|
|
|
(6,000
|
)
|
|
|
|
|
Change in fair value of contingent consideration
|
|
|
(2,976
|
)
|
|
|
(5,777
|
)
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
$
|
10,831
|
|
|
$
|
13,597
|
|
|
|
|
|
|
|
|
|
|
The fair value of the obligation for the AWS call/put option represents the present value of the
Companys right to acquire the remaining 49% interest in AWS from the noncontrolling interest holder at a fixed price of $11.0 million payable in shares of the Companys common stock. The noncontrolling interest holder has a put option to
sell the remaining 49% to the Company under the same terms. In accordance with ASC 480,
Distinguishing Liabilities from Equity
, the instrument is accounted for as a financing of the Companys purchase of the minority
interest. Accretion expense related to the increase in the net present value of the AWS call/put option is included in interest expense for the period.
In addition to the Companys assets and liabilities that are measured at fair value on a recurring basis, the Company is required, by generally accepted accounting principles in the United States, to
measure certain assets and liabilities at fair value on a nonrecurring basis after initial recognition. Generally, assets are measured at fair value on a nonrecurring basis as a result of impairment charges. During the year ended December 31,
2012, the Company recognized an impairment charge of $2.4 million related to the write-down of a customer relationship intangible associated with a portion of a prior business acquisition. The impairment review and associated write-down was
triggered by managements updated assessment of the reduced growth prospects of the business and the related impact on its expected financial performance. The impairment charge was equal to the amount which the asset groups carrying value
exceeded its fair value. The fair value was based on the discounted future cash flows of the asset group. During the year ended December 31, 2012, the Company also recognized an impairment charge of $3.7 million on three salt water disposal wells,
which developed technical problems which required the Company to suspend their use. The estimated future cash flows used to test the recoverability and measure the fair values of the disposal wells included an estimate of future expenditures
necessary to identify the source of the problem and to take corrective action to restore the wells functionality. During the year ended December 31, 2010, the Company recorded an impairment charge of approximately $3.4 million related to its
48% equity interest in China Bottles, as the decrease in fair value of the investment was deemed to be other than temporary. This expense is included in discontinued operations in the consolidated statements of operations for the year ended
December 31, 2010. Equity method investments are measured at fair value on a nonrecurring basis when deemed necessary, using observable inputs such as trading prices of the stock as well as using discounted cash flows, incorporating adjusted
available market discount rate information and the Companys estimates for liquidity risk.
2012 Offerings
On February 3, 2012, the Company issued 1,872,260 shares of common stock pursuant to the Companys Registration Statement on Form S-4 in connection with an acquisition by Fluids Management (Note
3).
On March 30, 2012, the Company sold 18,200,000 shares of common stock at a price of $4.40 per share in an
underwritten public offering pursuant to the Companys Registration Statement on Form S-3. The $74.4 million in net proceeds from the share issuance was used to finance a portion of the cash purchase price of the TFI Acquisition (Note 3).
On April 10, 2012, the Company issued 4,050,926 shares of common stock in connection with the TFI Acquisition in a
private placement pursuant to Section 4(a)(2) under the Securities Act (Note 3).
On May 3, 2012, the Company issued
2,458,396 shares of common stock pursuant to the Companys Form S-4 in connection with an acquisition by Fluids Management (Note 3).
On September 4, 2012, the Company issued 3,258,508 shares of common stock pursuant to the Companys Registration Statement on Form S-4 in connection with an acquisition of 51% of the
sellers equity by Fluids Management (Note 3).
On September 12, 2012, the Company issued 1,726,619 shares of common
stock in connection with a partial payment under an earn-out obligation (Note 13).
On November 30, 2012, the Company
issued 95,000,000 unregistered shares of common stock in connection with the Power Fuels acquisition in a private placement pursuant to Section 4(a)(2) under the Securities Act (Note 3).
Founders Units
On June 21, 2007, the Company sold 14,375,000 units for an aggregate purchase at a price of $71,875 or $0.005 per unit, to the Companys founders. Each unit consisted of one share of the
Companys common stock and one warrant to purchase one share of the Companys common stock. Upon the consummation of the Companys initial public offering and the partial exercise of the over-allotment option by the underwriters,
845,000 units were redeemed for $4,225. Of the remaining founders units and net of redemption, 13,152,746 founders units were issued to Heckmann Acquisition, LLC.
Initial Public Offering
On November 16, 2007, the Company sold
54,116,800 units (Units) in its initial public offering at a price of $8.00 per Unit and received proceeds of $428,071,040, net of underwriting discounts and commissions of $10,823,360 (including $19,482,048 of
F-26
deferred underwriting discounts and commissions placed in the trust account pending completion of a business combination). Each Unit consisted of one share of the Companys common
stock, $.001 par value, and one redeemable common stock purchase warrant. Each warrant entitled the holder to purchase from the Company one share of common stock at an exercise price of $6.00 per share commencing
on November 9, 2008. The warrants expired on November 9, 2011. In connection with the expiration of the warrants, the Units were terminated. The shares of the Companys common stock that were issued as part of the Units remain
outstanding.
Sponsors Warrants
Immediately prior to the Companys initial public offering, the initial stockholders of the Company purchased an aggregate of 7,000,000 warrants at $1.00 per warrant from the Company in a private
placement offering. The warrants sold in the private placement were identical to the warrants sold in the Companys initial public offering except that the initial stockholders warrants are not redeemable by the Company as long as
they are held by the initial stockholders. The initial stockholders warrants were entitled to registration rights and the Company satisfied its obligations with respect thereto. These warrants expired on November 9, 2011.
Preferred Stock
The Company is authorized to issue 1,000,000 shares of preferred stock with such designations, voting and other rights and preferences as may be determined from time to time by the Board of Directors. At
December 31, 2012, 2011 or 2010, no shares of preferred stock were outstanding.
Expiration and Cancellation of
Listed Units and Warrants
Prior to their expiration on November 9, 2011 described below, the Company had
outstanding publicly-issued Units, each consisting of one share of the Companys common stock and a warrant entitling the holder to purchase from us one share of the Companys common stock at an exercise price of $6.00. The Company also
had outstanding publicly-issued warrants entitling the holder to purchase from us one share of the Companys common stock at an exercise price of $6.00. The Units and the warrants were listed on the New York Stock Exchange, or NYSE. On
November 9, 2011, all of the then-outstanding unexercised listed warrants, including the warrants issued with the Units, expired at 5 p.m. Eastern time and were cancelled. Prior to their expiration, 7,985,209 of the listed warrants were
exercised for $47.9 million in cash. During the fourth quarter of 2011 and upon expiration, the remaining publicly listed warrants and units were delisted from the NYSE. The shares of the Companys common stock that were issued as part of
the Units remain outstanding and are listed and trade with the Companys shares of common stock on the NYSE under the symbol HEK. The Company also had outstanding privately-placed warrants exercisable for 941,176 shares of the
Companys common stock at an exercise price of $6.38 per share that expired unexercised on January 24, 2013, and 626,866 privately-placed warrants exercisable for 501,493 shares of our common stock at an exercise price of $2.02 per share.
In June 2012, 606,866 warrants were exercised as part of a cashless transaction that resulted in the issuance of 270,671 shares of the Companys common stock and in July 2012, 20,000 warrants were exercised resulting in the issuance of 16,000
shares of the Companys common stock in exchange for cash proceeds of $32,000.
(11)
|
Share-based Compensation
|
Stock Options
The Company measures the cost of employee services received in exchange for awards of stock options, based on the fair value of those awards at the date of grant. Awards of stock options generally vest in
equal increments over a three-year service period from the date of grant. The fair value of stock options on the date of grant is amortized to compensation expense on a straight-line basis over the requisite service period for the entire award, that
is, over the requisite service period of the last separately vesting portion of the award. The exercise price for stock options is equal to the market price of the Companys common stock on the date of grant. The maximum contractual term of
stock options is 10 years. The Company estimates the fair value of stock options using a Black-Scholes option-pricing model. The assumptions used to estimate the fair value of stock awards granted in the years ended December 31, 2012, 2011 and
2010 are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31,
|
|
|
|
2012
|
|
|
2011
|
|
|
2010
|
|
Volatility
|
|
|
40.10
|
%
|
|
|
34.6
|
%
|
|
|
34.8
|
%
|
Expected term (years)
|
|
|
10
|
|
|
|
10
|
|
|
|
10
|
|
Risk free interest rate
|
|
|
2.1
|
%
|
|
|
2.7
|
%
|
|
|
3.6
|
%
|
Expected dividend yield
|
|
|
0
|
%
|
|
|
0
|
%
|
|
|
0
|
%
|
F-27
The expected term of stock options represents the period of time that the stock options
granted are expected to be outstanding taking into consideration the contractual term of the options and post-vesting termination and option exercise behaviors of the Companys employees. The expected volatility is based on the historical price
volatility of the Companys common stock. The risk-free interest rate represents the U.S. Treasury bill rate for the expected term of the related stock options. The dividend yield represents the Companys anticipated cash dividend over the
expected term of the stock options.
Compensation cost for stock options recognized in operating results is included in
general and administrative expense in the consolidated statements of operations and was $2.0 million, $1.4 million and $0.5 million for the years ended December 31, 2012, 2011, and 2010, respectively. In addition, approximately $0.5 million of
stock-based compensation cost for stock options was included in the results from discontinued operations for the year ended December 31, 2011. This cost includes expense associated with the vesting of 333,500 stock options previously granted to
employees of China Water, which were accelerated upon closing of the Share Purchase Agreement (Note 18). The income tax benefit associated with stock option activity recognized in the consolidated statement of operations was $0.9 million for the
year ended December 31, 2012. There was no income tax benefit recognized in the consolidated statement of operations for the year ended December 31, 2011 and 2010 as all deferred tax assets were fully reserved by a valuation allowance.
A summary of stock option activity during 2012 is presented below (shares in 000s):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Options
|
|
Shares
|
|
|
Weighted-Average
Exercise Price
|
|
|
Weighted-Average
Remaining
Contractual
Term
(Years)
|
|
|
Aggregate
Intrinsic
Value
(in 000s)
|
|
Outstanding December 31, 2011
|
|
|
2,661
|
|
|
|
4.67
|
|
|
|
|
|
|
|
|
|
Granted
|
|
|
1,660
|
|
|
|
3.53
|
|
|
|
|
|
|
|
|
|
Exercised
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Forfeited or expired
|
|
|
(332
|
)
|
|
|
4.81
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding December 31, 2012
|
|
|
3,989
|
|
|
|
4.18
|
|
|
|
9.0
|
|
|
$
|
1,031
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercisable at December 31, 2012
|
|
|
1,540
|
|
|
|
4.30
|
|
|
|
7.6
|
|
|
$
|
114
|
|
As of December 31, 2012, there was approximately $4.3 million of unrecognized compensation expense
for employee stock options, which is expected to be recognized over a weighted-average period of approximately 1.1 years.
Restricted Stock
The Company measures the cost of employee services received in exchange for awards of restricted stock, based on the market value of the Companys common shares at the date of grant. Shares of
restricted common stock generally vest over a two or three year service period from the date of grant. The fair value of the restricted stock is amortized on a straight-line basis over the requisite service period for the entire award, that is, over
the requisite service period of the last separately vesting portion of the award.
Compensation cost for shares of restricted
common stock recognized in operating results is included in general and administrative expense in the consolidated statement of operations and was $1.6 million, $1.0 million and $0.4 million, for the years ended December 31, 2012, 2011 and
2010, respectively. The income tax benefit associated with restricted stock activity recognized in the consolidated statement of operations was $0.7 million for the year ended December 31, 2012. There was no income tax benefit recognized in the
consolidated statement of operations for the year ended December 31, 2011 and 2010 as all deferred tax assets were fully reserved by a valuation allowance.
A summary of non-vested restricted common stock activity is presented below (shares in 000s):
|
|
|
|
|
|
|
|
|
Non-Vested Restricted Stock
|
|
Shares
|
|
|
Weighted-Average
Grant-Date Fair
Value
|
|
Non-vested at December 31, 2011
|
|
|
549
|
|
|
|
5.76
|
|
Granted
|
|
|
423
|
|
|
|
4.16
|
|
Vested
|
|
|
(104
|
)
|
|
|
4.50
|
|
Forefited
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non-vested at December 31, 2012(a)
|
|
|
868
|
|
|
|
5.13
|
|
|
|
|
|
|
|
|
|
|
As of December 31, 2012, there was approximately $2.9 million of unrecognized compensation
expense for restricted common stock, which is expected to be recognized over a weighted-average period of approximately 1.5 years. The total fair value of shares vested during the years ended December 31, 2012, 2011 and 2010 was
approximately $0.4 million, $1.3 million and $1.1 million, respectively.
F-28
Approximately 142,900 shares of restricted common stock were issued in connection with the
acquisition of CVR in 2010 for a total cost of $0.6 million. Approximately $0.3 million of this cost was capitalized as part of the purchase price and $0.3 million of this cost was expensed as compensation cost over a one-year vesting period.
The components of the benefit for income taxes are as follows (in 000s):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2012
|
|
|
2011
|
|
|
2010
|
|
Current income tax expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
$
|
|
|
|
$
|
|
|
|
$
|
(2,746
|
)
|
State
|
|
|
1,673
|
|
|
|
500
|
|
|
|
61
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current
|
|
|
1,673
|
|
|
|
500
|
|
|
|
(2,685
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income tax benefit:
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
|
(53,812
|
)
|
|
|
(4,277
|
)
|
|
|
(719
|
)
|
State
|
|
|
(6,466
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Deferred
|
|
|
(60,278
|
)
|
|
|
(4,277
|
)
|
|
|
(719
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income tax benefit attributable to continuing operations
|
|
$
|
(58,605
|
)
|
|
$
|
(3,777
|
)
|
|
$
|
(3,404
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
A reconciliation of the benefit for income taxes and the amount computed by applying the statutory
federal income tax rate of 35% to loss before benefit for income taxes is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2012
|
|
|
2011
|
|
|
2010
|
|
U.S. federal income tax benefit at statutory rate
|
|
|
35.0
|
%
|
|
|
35.0
|
%
|
|
|
35.0
|
%
|
U.S. personal holding company tax
|
|
|
0.0
|
%
|
|
|
0.0
|
%
|
|
|
2.2
|
%
|
State and local income taxes, net of federal benefit
|
|
|
6.2
|
%
|
|
|
(8.4
|
%)
|
|
|
3.9
|
%
|
Compensation
|
|
|
(0.5
|
%)
|
|
|
(3.7
|
%)
|
|
|
(1.1
|
%)
|
Transaction costs
|
|
|
(3.0
|
%)
|
|
|
(10.2
|
%)
|
|
|
(1.1
|
%)
|
Change in fair value of contingent consideration
|
|
|
(1.5
|
%)
|
|
|
6.7
|
%
|
|
|
8.6
|
%
|
Loss on disposal of China Water
|
|
|
0.0
|
%
|
|
|
976.9
|
%
|
|
|
0.0
|
%
|
Change in valuation allowance
|
|
|
68.6
|
%
|
|
|
(909.5
|
%)
|
|
|
(26.0
|
%)
|
Other
|
|
|
(0.3
|
%)
|
|
|
10.4
|
%
|
|
|
3.4
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Benefit for income taxes
|
|
|
104.5
|
%
|
|
|
97.2
|
%
|
|
|
24.9
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-29
Significant components of the Companys deferred tax assets and liabilities as of
December 31, 2012 and 2011 are as follows (in 000s):
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2012
|
|
|
2011
|
|
Deferred tax assets:
|
|
|
|
|
|
|
|
|
Reserves
|
|
$
|
3,965
|
|
|
$
|
1,593
|
|
Net operating losses
|
|
|
85,123
|
|
|
|
97,733
|
|
Equity based compensation
|
|
|
1,434
|
|
|
|
521
|
|
Other
|
|
|
4,521
|
|
|
|
2,007
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
95,043
|
|
|
|
101,854
|
|
Less: Valuation allowance
|
|
|
(1,657
|
)
|
|
|
(40,188
|
)
|
|
|
|
|
|
|
|
|
|
Total deferred tax assets
|
|
|
93,386
|
|
|
|
61,666
|
|
|
|
|
|
|
|
|
|
|
Deferred tax liabilities:
|
|
|
|
|
|
|
|
|
Fixed assets and intangibles
|
|
|
(207,815
|
)
|
|
|
(68,467
|
)
|
Deferred financing costs
|
|
|
(2,023
|
)
|
|
|
|
|
Other
|
|
|
(45
|
)
|
|
|
(79
|
)
|
|
|
|
|
|
|
|
|
|
Total deferred tax liabilities
|
|
|
(209,883
|
)
|
|
|
(68,546
|
)
|
|
|
|
|
|
|
|
|
|
Net deferred tax liability
|
|
$
|
(116,497
|
)
|
|
$
|
(6,880
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31,
|
|
|
|
2012
|
|
|
2011
|
|
Current deferred tax assets, net:
|
|
|
|
|
|
|
|
|
Deferred tax assets
|
|
$
|
12,760
|
|
|
$
|
2,628
|
|
Deferred tax liabilities
|
|
|
(45
|
)
|
|
|
(6
|
)
|
Valuation allowance
|
|
|
(220
|
)
|
|
|
(2,622
|
)
|
|
|
|
|
|
|
|
|
|
Total current deferred tax assets, net
|
|
|
12,495
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term deferred tax liabilities, net:
|
|
|
|
|
|
|
|
|
Deferred tax assets
|
|
|
82,283
|
|
|
|
99,226
|
|
Deferred tax liabilities
|
|
|
(209,838
|
)
|
|
|
(68,540
|
)
|
Valuation allowance
|
|
|
(1,437
|
)
|
|
|
(37,566
|
)
|
|
|
|
|
|
|
|
|
|
Total long-term deferred tax liabilities, net
|
|
|
(128,992
|
)
|
|
|
(6,880
|
)
|
|
|
|
|
|
|
|
|
|
Net deferred tax liability
|
|
$
|
(116,497
|
)
|
|
$
|
(6,880
|
)
|
|
|
|
|
|
|
|
|
|
As of December 31, 2012, the Company had net operating loss (NOL) carryforwards for
federal income tax purposes of approximately $229.4 million, which expire in 2030-2032, and state NOL carryforwards of approximately $94.1 million, which expire in 2017-2032.
As required by U.S. GAAP, management assesses the recoverability of the Companys deferred tax assets on a regular basis and records a valuation allowance for any such assets where recoverability is
determined to be not more likely than not. The Companys evaluation of its valuation allowance resulted in a release of $38.5 of valuation allowance in 2012. The Company determined that realization of these deferred tax assets is more likely
than not based on future taxable income arising from the reversal of deferred tax liabilities that we acquired in connection with the TFI acquisition and the Power Fuels merger described in Note 3. The Company maintained a valuation allowance of
$1.7 million as of December 31, 2012 for certain state net operating loss carryforwards that management does not believe are more likely than not to be realized.
A reconciliation of the Companys valuation allowance on deferred tax assets for the years ended December 31, 2012, 2011 and 2010 is as follows (in 000s):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2012
|
|
|
2011
|
|
|
2010
|
|
Beginning balance at January 1,
|
|
$
|
40,188
|
|
|
$
|
4,854
|
|
|
$
|
1,256
|
|
Additions to valuation allowance
|
|
|
|
|
|
|
35,334
|
|
|
|
3,598
|
|
Valuation allowance release, net
|
|
|
(38,531
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ending balance at December 31,
|
|
$
|
1,657
|
|
|
$
|
40,188
|
|
|
$
|
4,854
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-30
Pursuant to United States Internal Revenue Code Section 382, if the Company underwent
an ownership change, the NOL carryforward limitations would impose an annual limit on the amount of the taxable income that may be offset by the Companys NOL generated prior to the ownership change. The Company has determined that an ownership
change occurred on November 30, 2012 as a result of the stock consideration transferred in the Power Fuels merger.
The Company does not expect any limitation under Section 382 to result in federal NOLs expiring unused. If a
subsequent ownership change were to occur, the Company may be unable to use a significant portion of its NOL to offset taxable income.
As of December 31, 2012, 2011, and 2010, the Company had no unrecognized tax benefits recorded. The Company recognizes potential accrued interest and penalties related to unrecognized tax benefits as
a component of income tax expense. No interest and penalties were accrued as of December 31, 2012 and 2011and no interest or penalties were recorded for both fiscal 2012 and 2011.
The Company and its subsidiaries are subject to the following significant taxing jurisdictions: U.S. federal, Pennsylvania, Louisiana,
North Dakota, Texas, West Virginia, Arizona, and Oregon. The Company has had NOLs in various years for federal purposes and for many states. The statute of limitations for a particular tax year for examination by the Internal Revenue Service is
generally three years subsequent to the filing of the associated tax return. However, the Internal Revenue Service can adjust NOL carryovers up to three years subsequent to the last year in which the loss carryover is finally used. Accordingly,
there are multiple years open to examination. The statute of limitations is generally three to four years for many of the states where the Company operates.
The Internal Revenue Service is examining the Companys federal income tax returns for the years ended December 31, 2008 through 2010. The Company does not expect the result of this audit to
significantly change the Companys total unrecognized tax benefits in the next twelve months, but the outcome of tax examinations is uncertain, and unforeseen results can occur. The Company is currently not under income tax examination in any
other tax jurisdictions.
(13)
|
Commitments and Contingencies
|
At December 31, 2012, the Company had total available irrevocable letters of credit facilities outstanding of $1.0
million. Such irrevocable commercial and standby letters of credit facilities support various agreements, leases, and insurance policies.
Leases
Included in property and equipment in the consolidated
balance sheets are the following assets held under capital leases at December 31, 2012 (in 000s):
|
|
|
|
|
|
|
2012
|
|
Leased equipment
|
|
$
|
20,771
|
|
Less accumulated depreciation
|
|
|
(2,578
|
)
|
|
|
|
|
|
Leased equipment
|
|
$
|
18,193
|
|
|
|
|
|
|
Capital lease obligations consist primarily of vehicle leases with periods expiring at various dates
through 2017 at variable interest rates and fixed interest rates, which were approximately 3.1% at December 31, 2012. Capital lease obligations amounted to $17.9 million at December 31, 2012. There were no capital lease obligations at
December 31, 2011.
Future minimum lease payments, by year and in the aggregate, for capital leases are as follows at (in
000s):
|
|
|
|
|
|
|
December 31,
|
|
2013
|
|
$
|
4,277
|
|
2014
|
|
|
4,160
|
|
2015
|
|
|
4,041
|
|
2016
|
|
|
3,566
|
|
2017
|
|
|
3,380
|
|
Thereafter
|
|
|
|
|
|
|
|
|
|
Total minimum lease payments
|
|
$
|
19,424
|
|
Less amount representing executor costs
|
|
|
(211
|
)
|
|
|
|
|
|
Net minimum lease payments
|
|
$
|
19,213
|
|
Less amount representing interest (3.1% at December 31, 2012)
|
|
|
(1,336
|
)
|
|
|
|
|
|
Present value of net minimum lease payments
|
|
$
|
17,877
|
|
|
|
|
|
|
F-31
The Company also rents equipment, real estate and certain office equipment under operating
leases. Certain real estate leases require the Company to pay maintenance, insurance, taxes and certain other expenses in addition to the stated rentals. Lease expense under operating leases and rental contracts amounted to $10.5 million, $0.6
million and $0.2 million for the years ended December 31, 2012, 2011 and 2010, respectively.
Future minimum lease
payments, by year and in the aggregate, for noncancelable operating leases with initial or remaining terms of one year or more are as follows at (in 000s):
|
|
|
|
|
|
|
December 31,
|
|
2013
|
|
$
|
3,610
|
|
2014
|
|
|
2,777
|
|
2015
|
|
|
1,961
|
|
2016
|
|
|
1,594
|
|
2017
|
|
|
1,112
|
|
Thereafter
|
|
|
2,053
|
|
|
|
|
|
|
Total minimum lease payments
|
|
$
|
13,107
|
|
|
|
|
|
|
Environmental Liabilities
We are subject to the environmental protection and health and safety laws and related rules and regulations of the United States and of
the individual states, municipalities and other local jurisdictions where we operate. The Companys Fluids Management business is subject to rules and regulations promulgated by the Texas Railroad Commission, the Texas Commission on
Environmental Quality, the Louisiana Department of Natural Resources, the Louisiana Department of Environmental Quality, the Ohio Department of Natural Resources and the Pennsylvania Department of Environmental Protection, the North Dakota
Department of Health, the North Dakota Industrial Commission, Oil and Gas Division, and the North Dakota State Water Commission and, in Montana, the rules and regulations of the Montana Department of Environmental Quality and the Montana Board of
Oil and Gas, among others. These laws, rules and regulations address environmental, health and safety and related concerns, including water quality and employee safety. We have installed safety, monitoring and environmental protection equipment
such as pressure sensors and relief valves, and have established reporting and responsibility protocols for environmental protection and reporting to such relevant local environmental protection departments as required by law.
The Companys Recycling business involves the use, handling, storage and contracting for recycling or disposal of environmentally
sensitive materials, such as waste motor oil and filters, solvents, transmission fluid, antifreeze, lubricants and degreasing agents. Accordingly, the Companys Recycling business is subject to regulation by various federal, state, and
local authorities with respect to health, safety and environmental quality and standards. The Recycling business is also subject to laws, ordinances, and regulations governing the investigation and remediation of contamination at facilities we
operate or to which we send hazardous substances for treatment, recycling or disposal. In particular, the United States Comprehensive Environmental Response, Compensation and Liability Act, or CERCLA, imposes joint, strict, and
several liability on owners or operators of facilities at, from, or to which a release of hazardous substances has occurred, parties that generated hazardous substances that were released at such facilities and parties that transported or arranged
for the transportation of hazardous substances to such facilities. A majority of states have adopted statutes comparable to, and in some cases more stringent than, CERCLA.
Management believes that we are in material compliance with all applicable environmental protection laws and regulations in the United
States and the individual states in which we operate. During the fourth quarter of 2012, the Company recorded a $1.4 million environmental accrual for the estimated cost to comply with a Louisiana Department of Environmental Quality requirement that
the Company test and monitor the soil at certain locations to confirm that prior saltwater spills were successfully remediated. Management believes that there are no unrecorded liabilities in connection with our compliance with environmental laws
and regulations.
Legal and Insurance Matters
The Company is party to various litigation matters, including regulatory and administrative proceedings arising out of the normal course
of business, the more significant of which are summarized below. The ultimate outcome of each of these matters cannot presently be determined, nor can the liability that could potentially result from a negative outcome be reasonably estimated
presently for every case. The liability we may ultimately incur with respect to any one of these matters in the event of a negative outcome may be in excess of amounts currently accrued with respect to such matters and, as a result of these matters,
may potentially be material to our financial position or results of operations. We review our litigation activities and determine if an unfavorable outcome to us is considered remote, reasonably possible or
probable as defined by U.S. GAAP. Where we have determined an unfavorable outcome is probable and is reasonably estimable, we have accrued for potential litigation losses. In addition to the matters described below, we are involved in
various other claims and legal actions, including regulatory and administrative proceedings arising out of the normal course of our business. We do not expect that the outcome of such other claims and legal actions will have a material adverse
effect on our financial position or results of operations.
F-32
Class Action
. On May 21, 2010, Richard P. Gielata, an individual purporting to
act on behalf of stockholders, served a class action lawsuit filed May 6, 2010 against the Company and various directors and officers in the United States District Court for the District of Delaware captioned
In re Heckmann Corporation
Securities Class Action
(Case No. 1:10-cv-00378-JJF-MPT) (the Class Action). The Class Action alleges violations of federal securities laws in connection with the acquisition of China Water. The Company responded by filing a
motion to transfer the Class Action to California and a motion to dismiss the case. On October 6, 2010, the Magistrate Judge issued a report and recommendation to the District Court Judge to deny the motion to transfer. On October 8, 2010,
the court-appointed lead plaintiff, Matthew Haberkorn, filed an Amended Class Action Complaint that adds China Water as a defendant. On October 25, 2010, the Company filed objections to the Magistrate Judges report and recommendation on
the motion to transfer. The court adopted the report and recommendation on the motion to transfer on March 31, 2011. The Company filed a motion to dismiss the Amended Class Action Complaint and a reply to lead plaintiffs opposition to the
motion to dismiss. On June 16, 2011, the Magistrate Judge issued a report and recommendation to the District Court Judge to deny the motion to dismiss. The Company filed objections to the Magistrate Judges report and recommendation on the
motion to dismiss and Plaintiffs filed a response. On October 25, 2011, the court heard oral argument on the Companys objections to the report and recommendation on the motion to dismiss. The court has not yet ruled on the
objections. On February 2, 2012, Plaintiff filed motion to modify the automatic discovery stay in place pursuant to the Private Securities Litigation Reform Act. The Company filed an opposition on February 13, 2012. On
February 15, 2012, the Magistrate Judge entered an order modifying the discovery stay and requiring the Company to produce documents to plaintiff that have been produced in the Derivative Action described below. On
February 2, 2012, Plaintiff filed motion to modify the automatic discovery stay in place pursuant to the Private Securities Litigation Reform Act. The Company filed an opposition on February 13, 2012. On February 15, 2012, the
Magistrate Judge entered an order modifying the discovery stay and requiring the Company to produce documents to Plaintiff that have been produced in the derivative action pending in the Superior Court of California, County of Riverside captioned
Hess v. Heckmann, et
al. On May 25, 2012, the court entered a memorandum order overruling the Companys objections, adopting the Magistrate Judges report and recommendation, and denying the Companys motion
to dismiss. On June 25, 2012, the court entered a scheduling order setting forth a schedule for, among other things, discovery and dispositive motions, and document discovery has commenced. On July 9, 2012, the Company
filed its Answer to the Amended Class Action Complaint. On September 19, 2012, the Company filed a Motion for Partial Summary Judgment and a Motion for Proposed Briefing Schedule. The Magistrate Judge denied the Motion for Proposed Briefing
Schedule on October 4, 2012 and the Company filed objections to the Magistrate Judges ruling. On January 16, 2013, the Court adopted the Magistrate Judges ruling and denied the Companys request for a briefing schedule on
its Motion for Partial Summary Judgment. On October 19, 2012, plaintiff filed a motion to certify a class and appoint class representatives and class counsel. On January 18, 2013, the Company filed its opposition and a motion to exclude
the declaration of plaintiffs class certification expert. On February 19, 2013, Plaintiff filed a reply brief. A hearing on Plaintiffs motion to certify a class and appoint class representatives and class counsel has not been
scheduled. The Company intends to vigorously defend this case.
Derivative Action
On November 18, 2010,
Melissa Hess filed a stockholder derivative complaint, purportedly on behalf of the Company, against various officers and directors in the Superior Court of California, County of Riverside captioned
Hess v. Heckmann, et al.
(Case No.
INC10010407) (the Derivative Action). The Derivative Action alleges claims for breach of fiduciary duty, waste of corporate assets, and unjust enrichment in connection with the acquisition of China Water. The Company responded to the
Derivative Action on February 1, 2011 by filing a motion to stay the case until the Class Action is resolved and a demurrer seeking to dismiss the case. The Company filed a reply to Plaintiffs opposition to the motion to stay and demurrer
on May 25, 2011. The court held a hearing on the demurrer and motion to stay on June 21, 2011. On July 20, 2011, the court issued orders overruling the Companys demurrer and denying its motion to stay the Derivative Action. On
August 24, 2011, the Companys board of directors formed a special litigation committee and delegated to the special litigation committee the Boards full power and authority to investigate the Derivative Action to determine whether
it is in the best interests of the Company to allow the Derivative Action to proceed on behalf of the Company. On September 2, 2011, the Company filed a motion to stay the Derivative Action pending completion of the special litigation
committees investigation and determination. On September 26, 2011, the Court held a hearing on the Companys motion to stay. On October 3, 2011, the court issued an order denying the Companys motion to stay without
prejudice and a separate order requiring Defendants to respond to plaintiffs request for production of documents within thirty days. On October 28, 2011, the special litigation committee filed a motion to stay the Derivative Action
pending completion of its investigation and determination. After meeting and conferring on discovery matters, on December 2, 2011, the special litigation committee, plaintiff and defendants entered into a stipulation and proposed
order to vacate the motion to stay filed by the special litigation committee, and, on December 5, 2011, the Court entered the order. After meeting and conferring on discovery matters, on December 2, 2011, the special litigation
committee, Plaintiff and Defendants entered into a stipulation and proposed order to vacate the motion to stay filed by the special litigation committee, and, on December 5, 2011, the Court entered the order. On September 14, 2012, the
Company filed a Motion to Dismiss or, in the alternative, a Motion for Summary Judgment based on the determination of the special litigation committees determination that it is not in the best interests of the Company and its current
shareholders to pursue the claims pled in the complaint and the special litigation committees decision to move to terminate the Derivative Action. A hearing date for the Companys motion is not currently scheduled.
F-33
The Company has not recorded any liabilities for the Class Action and Derivative Action
matters on the basis that such liabilities are currently neither probable or estimable.
In addition, on June 10, 2011,
the Company received a subpoena from the Denver Regional Office of the SEC seeking information and documents concerning our acquisition of China Water in 2008. We are cooperating fully with the SEC with respect to its requests.
Contingent Consideration for Acquisitions
Appalachian Water Services, LLC Acquisition
The seller of the membership interests in Appalachian Water Services, LLC (AWS) is entitled to receive additional consideration equal
to $1.5 million, payable entirely in shares of the Companys common stock, in the event that EBITDA, as defined in the membership interest purchase agreement for any consecutive twelve months from September 1, 2012 to and ending on
August 31, 2014, is $4.0 million. The additional consideration is capped at $1.5 million.
All Phase Acquisition
In addition to the initial purchase price, the Company was required to make additional payments to the former shareholders of All Phase, which the Company acquired on June 15, 2012, based upon the achievement of certain volume targets
over the remainder of 2012. The Company settled this obligation in 2013 in exchange for a $0.4 million payment to the former shareholders.
Keystone Vacuum, Inc. Acquisition
In addition to the initial purchase price, the Company may make additional payments to the sellers of Keystone, which the Company acquired on
February 3, 2012, for each of fiscal years ended December 31, 2012 through 2015, in which Keystones adjusted EBITDA (as defined in and calculated in accordance with the asset purchase agreement related to the Keystone Vacuum, Inc.
acquisition) related to the construction portion of the acquired businesses is greater than applicable adjusted EBITDA targets. Any additional amount payable would be payable in shares of the Companys common stock. Any such additional payments
are capped at an aggregate value of $7.5 million.
Complete Vacuum and Rentals, Inc. Acquisition
In addition to
the initial purchase price, the Company may make additional payments to the former shareholders of Complete Vacuum and Rentals, Inc. (CVR), which the Company acquired on November 30, 2010. For each of the years ended
December 31, 2011 through 2013, in which CVR achieves targeted adjusted EBITDA (as defined in and calculated in accordance with the stock purchase agreement related to the CVR acquisition) of $20.0 million, we could be required to pay
CVRs former shareholders an additional $2.0 million plus one-half of the amount by which adjusted EBITDA exceeds $20.0 million for the relevant year up to an aggregate maximum payment of $12.0 million (the Earn-Out Payments). The
Earn-Out Payments are payable in a combination of 70% cash and 30% in shares of the Companys common stock (based on the trading price of the Companys common stock at the time any such payment is made). On September 12, 2012, the
Company entered into a settlement agreement with the former owners of CVR whereby, among other settled items relating to pre- and post-closing indemnification obligations of the parties and including dismissal of a lawsuit, the Company delivered to
the former owners 1,726,619 shares of the Companys common stock representing $6.0 million in value at the time of the issuance as an Earn-Out Payment for the fiscal year ended December 31, 2011. Accordingly, the balance of the remaining
Earn-Out Payments for the fiscal years ending December 31, 2012 and 2013, respectively, and in the aggregate cannot exceed $6.0 million which, pursuant to the terms of the settlement agreement, will be paid, if at all, in shares of the
Companys common stock.
The carrying values of the Companys contingent consideration obligations were $10.8
million and $13.6 million at December 31, 2012 and 2011, respectively.
(14)
|
Employee Benefit Plans
|
Two of the Companys subsidiaries sponsor a defined contribution 401(k) plan that are subject to the
provisions of the Employee Retirement Income Security Act of 1974 (ERISA). Under these plans, the Companys subsidiaries match a percentage of the participants contributions up to a specified amount. Company contributions to
the plans were $0.3 million for the year the year ended December 31, 2012.
(15)
|
Affiliated Company Transactions
|
The Executive Chairman of the Companys board of directors, Richard J. Heckman, is the sole member of an LLC that
owns an aircraft used periodically by members of management for business related travel. Reimbursement paid to the affiliate in exchange for use of the aircraft was $1.2 million, $0.9 million and $0.5 million for the years ended December 31,
2012, 2011 and 2010, respectively. There were no accounts payable due to the affiliate at December 31, 2012.
The
Companys Chief Executive Officer, Mark D. Johnsrud, is the sole member of an entity that owns apartment buildings in North Dakota. The apartments are rented to certain of the Companys employees at rates that are equal to or below market.
Rent payments are made through employee payroll deductions.
F-34
The Company periodically purchases fresh water from a proprietorship owned by the
Companys Chief Executive Officer and Vice Chairman, Mark D. Johnsrud. The fresh water is resold to oil and gas exploration companies for use in hydraulic fracturing activities. There were no fresh water purchases made by the Company during the
one-month ended December 2012 and no accounts payable due to the affiliate at December 31, 2012. Purchases made by Power Fuels prior to its merger with the Company totaled approximately $2.4 million during the eleven months ended
November 30, 2012.
The Companys Chief Executive Officer and Vice Chairman, Mark D. Johnsrud, is the sole member of
an entity that owns land in North Dakota on which five of the Companys saltwater disposal wells are situated. The Company has agreed to pay Mr. Johnsrud a per barrel royalty fee in exchange for using the disposal wells, which the Company
concluded is consistent with rates charged by non-affiliated third parties in the area. Royalties paid by the Company were $10,000 for the one month ended December 31, 2012. Royalties paid by Power Fuels prior to its merger with the Company
totaled approximately $32,000 during the eleven months ended November 30, 2012. Royalties payable to the affiliate were $10,400 at December 31, 2012.
Following the TFI Acquisition on April 10, 2012, management determined the Company would be operated and managed
through two divisions, which are also the Companys reportable segments: (a) the Fluids Management Division (which now includes PowerFuels and which the Company previously referred to as Heckmann Water Resources or HWR); and (b) the
Recycling Division (which consists of TFI and which the Company previously referred to as Heckmann Environmental Services or HES). The composition of the Companys reportable segments is consistent with that used by the Companys chief
operating decision maker to evaluate performance and allocate resources. Refer to Note 1 for information on the types of services from which each segment derives its revenues. The consolidated financial information and the Recycling segment
financial information include the results of operations for TFI from April 10, 2012. Accordingly, no historical comparative information is provided for the Recycling segment for the years ended December 31, 2011 and December 31, 2010.
The Company evaluates business segment performance based on results from continuing operations before income taxes exclusive of corporate general and administrative costs and interest expense, which are not allocated to the segments.
The financial information for the Companys reportable segments is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Recycling
|
|
|
Fluids
Management
|
|
|
Corporate
|
|
|
Total
|
|
|
|
(in millions)
|
|
Year ended December 31, 2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
$
|
95.3
|
|
|
$
|
256.7
|
|
|
$
|
|
|
|
$
|
352.0
|
|
Depreciation and amortization
|
|
|
10.9
|
|
|
|
47.6
|
|
|
|
|
|
|
|
58.5
|
|
Income (loss) from continuing operations before income taxes
|
|
|
13.3
|
|
|
|
(23.3
|
)
|
|
|
(46.1
|
)
|
|
|
(56.1
|
)
|
Additions to fixed assets
|
|
|
2.0
|
|
|
|
60.9
|
|
|
|
|
|
|
|
62.9
|
|
Goodwill
|
|
|
139.9
|
|
|
|
415.2
|
|
|
|
|
|
|
|
555.1
|
|
Total assets (a)
|
|
|
295.8
|
|
|
|
1,300.8
|
|
|
|
47.7
|
|
|
|
1,644.3
|
|
|
|
|
|
|
Year ended December 31, 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
$
|
|
|
|
$
|
156.8
|
|
|
$
|
|
|
|
$
|
156.8
|
|
Depreciation and amortization
|
|
|
|
|
|
|
25.3
|
|
|
|
|
|
|
|
25.3
|
|
Income (loss) from continuing operations before income taxes
|
|
|
|
|
|
|
10.4
|
|
|
|
(14.3
|
)
|
|
|
(3.9
|
)
|
Additions to fixed assets
|
|
|
|
|
|
|
156.8
|
|
|
|
|
|
|
|
156.8
|
|
Goodwill
|
|
|
|
|
|
|
90.0
|
|
|
|
|
|
|
|
90.0
|
|
Total assets (a)
|
|
|
|
|
|
|
447.4
|
|
|
|
92.3
|
|
|
|
539.7
|
|
|
|
|
|
|
|
|
Bottled
Water
Products
|
|
|
Fluids
Management
|
|
|
Corporate
|
|
|
Total
|
|
Year ended December 31, 2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
$
|
|
|
|
$
|
15.2
|
|
|
$
|
|
|
|
$
|
15.2
|
|
Depreciation and amortization
|
|
|
|
|
|
|
4.6
|
|
|
|
|
|
|
|
4.6
|
|
Income (loss) from continuing operations before income taxes
|
|
|
|
|
|
|
(5.7
|
)
|
|
|
(8.0
|
)
|
|
|
(13.7
|
)
|
Additions to fixed assets
|
|
|
|
|
|
|
20.4
|
|
|
|
|
|
|
|
20.4
|
|
Goodwill
|
|
|
|
|
|
|
41.0
|
|
|
|
|
|
|
|
41.0
|
|
Total assets excluding those applicable to discontinued operations (a)
|
|
|
|
|
|
|
174.3
|
|
|
|
181.4
|
|
|
|
355.7
|
|
Total assets held for sale (b)
|
|
|
45.6
|
|
|
|
|
|
|
|
|
|
|
|
45.6
|
|
(a)
|
Total assets exclude intercompany receivables eliminated in consolidation.
|
(b)
|
Represents the carrying value of the assets of discontinued operations.
|
F-35
Revenues from one customer of the Recycling Division represented approximately 34% of the
divisions total revenue for the year ended December 31, 2012. Revenues from three customers of the Fluids Management Division represented approximately 52% of the divisions total revenue for the year ended December 31, 2012.
As described in Note 1, the Company intends to commence an internal reorganization during 2013, which could impact the
composition of the Companys reportable segments.
(17)
|
Subsidiary Guarantors
|
The obligations of Heckmann Corporation under the 2018 Notes are jointly and severally, fully and unconditionally
guaranteed by certain of the Companys subsidiaries. The following tables present condensed consolidating financial information for Heckmann Corporation (the Parent Issuer), certain 100% wholly-owned subsidiaries (the
Wholly-Owned Subsidiary Guarantors) and Appalachian Water Services, LLC, a 51% owned subsidiary (the Non Wholly-Owned Subsidiary Guarantor), as of and for the year ended December 31, 2012 and condensed consolidating
financial information for the Parent Issuer, the wholly-owned Subsidiary Guarantors and China Water (the Non-Guarantor) as of and for the years ended December 31, 2011 and 2010 (in 000s):
Heckmann Corporation and Subsidiaries
Condensed Consolidating Balance Sheet
As of December 31, 2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(dollars in thousands)
|
|
Heckmann
Corp.
(Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
AWS
|
|
|
Eliminations
|
|
|
Consolidated
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
5,819
|
|
|
$
|
9,536
|
|
|
$
|
856
|
|
|
$
|
|
|
|
$
|
16,211
|
|
Restricted cash
|
|
|
|
|
|
|
3,536
|
|
|
|
|
|
|
|
|
|
|
|
3,536
|
|
Accounts receivablenet
|
|
|
|
|
|
|
116,768
|
|
|
|
760
|
|
|
|
|
|
|
|
117,528
|
|
Other current assets
|
|
|
439,842
|
|
|
|
42,785
|
|
|
|
2
|
|
|
|
(454,013
|
)
|
|
|
28,616
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
445,661
|
|
|
|
172,625
|
|
|
|
1,618
|
|
|
|
(454,013
|
)
|
|
|
165,891
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
|
44
|
|
|
|
595,293
|
|
|
|
9,533
|
|
|
|
|
|
|
|
604,870
|
|
Equity investments
|
|
|
957,976
|
|
|
|
8,279
|
|
|
|
|
|
|
|
(957,976
|
)
|
|
|
8,279
|
|
Intangible assets, net
|
|
|
|
|
|
|
283,248
|
|
|
|
1,450
|
|
|
|
|
|
|
|
284,698
|
|
Goodwill
|
|
|
|
|
|
|
544,647
|
|
|
|
10,444
|
|
|
|
|
|
|
|
555,091
|
|
Other
|
|
|
24,408
|
|
|
|
1,102
|
|
|
|
|
|
|
|
|
|
|
|
25,510
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$
|
1,428,089
|
|
|
$
|
1,605,194
|
|
|
$
|
23,045
|
|
|
$
|
(1,411,989
|
)
|
|
$
|
1,644,339
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$
|
757
|
|
|
$
|
28,566
|
|
|
$
|
215
|
|
|
$
|
|
|
|
$
|
29,538
|
|
Accrued expenses
|
|
|
33,492
|
|
|
|
470,724
|
|
|
|
62
|
|
|
|
(454,013
|
)
|
|
|
50,265
|
|
Current portion of contigent consideration
|
|
|
|
|
|
|
1,968
|
|
|
|
|
|
|
|
|
|
|
|
1,968
|
|
Current portion of long-term debt
|
|
|
|
|
|
|
4,699
|
|
|
|
|
|
|
|
|
|
|
|
4,699
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
34,249
|
|
|
|
505,957
|
|
|
|
277
|
|
|
|
(454,013
|
)
|
|
|
86,470
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income taxes
|
|
|
|
|
|
|
128,992
|
|
|
|
|
|
|
|
|
|
|
|
128,992
|
|
Long-term debt, less current portion
|
|
|
546,079
|
|
|
|
15,348
|
|
|
|
|
|
|
|
|
|
|
|
561,427
|
|
Long-term contingent consideration
|
|
|
|
|
|
|
7,363
|
|
|
|
1,500
|
|
|
|
|
|
|
|
8,863
|
|
Other long-term liabilities
|
|
|
|
|
|
|
1,805
|
|
|
|
9,021
|
|
|
|
|
|
|
|
10,826
|
|
Total shareholders equity
|
|
|
847,761
|
|
|
|
945,729
|
|
|
|
12,247
|
|
|
|
(957,976
|
)
|
|
|
847,761
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND EQUITY
|
|
$
|
1,428,089
|
|
|
$
|
1,605,194
|
|
|
$
|
23,045
|
|
|
$
|
(1,411,989
|
)
|
|
$
|
1,644,339
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heckmann Corporation and Subsidiaries
Condensed Consolidating Balance Sheet
As of December 31, 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(dollars in thousands)
|
|
Heckmann
Corp. (Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
Non-
Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
79,528
|
|
|
$
|
666
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
80,194
|
|
Marketable securities
|
|
|
5,169
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,169
|
|
Accounts receivablenet
|
|
|
|
|
|
|
47,985
|
|
|
|
|
|
|
|
|
|
|
|
47,985
|
|
Other current assets
|
|
|
214,866
|
|
|
|
9,325
|
|
|
|
|
|
|
|
(217,868
|
)
|
|
|
6,323
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
299,563
|
|
|
|
57,976
|
|
|
|
|
|
|
|
(217,868
|
)
|
|
|
139,671
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
|
265
|
|
|
|
269,789
|
|
|
|
|
|
|
|
|
|
|
|
270,054
|
|
Investments in subsidiaries
|
|
|
185,305
|
|
|
|
7,682
|
|
|
|
|
|
|
|
(185,305
|
)
|
|
|
7,682
|
|
Intangible assets, net
|
|
|
|
|
|
|
29,489
|
|
|
|
|
|
|
|
|
|
|
|
29,489
|
|
Goodwill
|
|
|
|
|
|
|
90,008
|
|
|
|
|
|
|
|
|
|
|
|
90,008
|
|
Other
|
|
|
2,663
|
|
|
|
114
|
|
|
|
|
|
|
|
|
|
|
|
2,777
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$
|
487,796
|
|
|
$
|
455,058
|
|
|
$
|
|
|
|
$
|
(403,173
|
)
|
|
$
|
539,681
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$
|
|
|
|
$
|
19,992
|
|
|
$
|
|
|
|
$
|
|
|
|
|
19,992
|
|
Accrued expenses
|
|
|
5,812
|
|
|
|
223,749
|
|
|
|
|
|
|
|
(217,868
|
)
|
|
|
11,693
|
|
Current portion of contigent consideration
|
|
|
|
|
|
|
5,730
|
|
|
|
|
|
|
|
|
|
|
|
5,730
|
|
Current portion of long-term debt
|
|
|
10,500
|
|
|
|
1,414
|
|
|
|
|
|
|
|
|
|
|
|
11,914
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
16,312
|
|
|
|
250,885
|
|
|
|
|
|
|
|
(217,868
|
)
|
|
|
49,329
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income taxes
|
|
|
|
|
|
|
6,880
|
|
|
|
|
|
|
|
|
|
|
|
6,880
|
|
Long-term debt, less current portion
|
|
|
129,674
|
|
|
|
2,482
|
|
|
|
|
|
|
|
|
|
|
|
132,156
|
|
Long-term contingent consideration
|
|
|
|
|
|
|
7,867
|
|
|
|
|
|
|
|
|
|
|
|
7,867
|
|
Other long-term liabilities
|
|
|
|
|
|
|
1,639
|
|
|
|
|
|
|
|
|
|
|
|
1,639
|
|
Total shareholders equity
|
|
|
341,810
|
|
|
|
185,305
|
|
|
|
|
|
|
|
(185,305
|
)
|
|
|
341,810
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND EQUITY
|
|
$
|
487,796
|
|
|
$
|
455,058
|
|
|
$
|
|
|
|
$
|
(403,173
|
)
|
|
$
|
539,681
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heckmann Corporation and Subsidiaries
Condensed Consolidating Statement of Operations
For the Year Ended December 31, 2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(dollars in thousands)
|
|
Heckmann
Corp. (Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
AWS
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Revenue
|
|
$
|
|
|
|
$
|
350,575
|
|
|
$
|
1,408
|
|
|
$
|
|
|
|
$
|
351,983
|
|
Cost of goods sold
|
|
|
|
|
|
|
(304,742
|
)
|
|
|
(914
|
)
|
|
|
|
|
|
|
(305,656
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
|
|
|
|
45,833
|
|
|
|
494
|
|
|
|
|
|
|
|
46,327
|
|
Operating expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Selling, general and administrative expenses
|
|
|
17,362
|
|
|
|
47,168
|
|
|
|
84
|
|
|
|
|
|
|
|
64,614
|
|
Impairment of long-lived assets
|
|
|
|
|
|
|
3,658
|
|
|
|
|
|
|
|
|
|
|
|
3,658
|
|
Impairment of intangible asset
|
|
|
|
|
|
|
2,372
|
|
|
|
|
|
|
|
|
|
|
|
2,372
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from operations
|
|
|
(17,362
|
)
|
|
|
(7,365
|
)
|
|
|
410
|
|
|
|
|
|
|
|
(24,317
|
)
|
Interest expense, net
|
|
|
(25,200
|
)
|
|
|
(1,165
|
)
|
|
|
(252
|
)
|
|
|
|
|
|
|
(26,617
|
)
|
Loss on extinguishment of debt
|
|
|
(2,638
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,638
|
)
|
Income from equity investment
|
|
|
(9,958
|
)
|
|
|
12
|
|
|
|
|
|
|
|
9,958
|
|
|
|
12
|
|
Other, net
|
|
|
(920
|
)
|
|
|
(1,598
|
)
|
|
|
|
|
|
|
|
|
|
|
(2,518
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) Income from continuing operations before income taxes before income taxes
|
|
|
(56,078
|
)
|
|
|
(10,116
|
)
|
|
|
158
|
|
|
|
9,958
|
|
|
|
(56,078
|
)
|
Income tax benefit (expense)
|
|
|
58,605
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
58,605
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income attributable to common stockholders
|
|
$
|
2,527
|
|
|
$
|
(10,116
|
)
|
|
$
|
158
|
|
|
$
|
9,958
|
|
|
$
|
2,527
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heckmann Corporation and Subsidiaries
Condensed Consolidating Statement of Operations
For the Year Ended December 31, 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(dollars in thousands)
|
|
Heckmann
Corp. (Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
Non-
Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Revenue
|
|
$
|
|
|
|
$
|
156,837
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
156,837
|
|
Cost of sales
|
|
|
|
|
|
|
(123,509
|
)
|
|
|
|
|
|
|
|
|
|
|
(123,509
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
|
|
|
|
33,328
|
|
|
|
|
|
|
|
|
|
|
|
33,328
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General and administrative expenses
|
|
|
11,061
|
|
|
|
25,590
|
|
|
|
|
|
|
|
|
|
|
|
36,651
|
|
Pipeline start-up and commissioning
|
|
|
|
|
|
|
2,089
|
|
|
|
|
|
|
|
|
|
|
|
2,089
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating expenses
|
|
|
11,061
|
|
|
|
27,679
|
|
|
|
|
|
|
|
|
|
|
|
38,740
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
(11,061
|
)
|
|
|
5,649
|
|
|
|
|
|
|
|
|
|
|
|
(5,412
|
)
|
Interest expense, net
|
|
|
(2,437
|
)
|
|
|
(1,806
|
)
|
|
|
|
|
|
|
|
|
|
|
(4,243
|
)
|
Loss from equity investment
|
|
|
9,482
|
|
|
|
(462
|
)
|
|
|
|
|
|
|
(9,482
|
)
|
|
|
(462
|
)
|
Other, net
|
|
|
131
|
|
|
|
6,101
|
|
|
|
|
|
|
|
|
|
|
|
6,232
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss (Income) from continuing operations before income taxes
|
|
|
(3,885
|
)
|
|
|
9,482
|
|
|
|
|
|
|
|
(9,482
|
)
|
|
|
(3,885
|
)
|
Income tax benefit
|
|
|
3,777
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,777
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations
|
|
|
(108
|
)
|
|
|
9,482
|
|
|
|
|
|
|
|
(9,482
|
)
|
|
|
(108
|
)
|
Loss from discontinued operations, net of income taxes
|
|
|
(22,898
|
)
|
|
|
|
|
|
|
(22,898
|
)
|
|
|
22,898
|
|
|
|
(22,898
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss attributable to common stockholders
|
|
$
|
(23,006
|
)
|
|
$
|
9,482
|
|
|
$
|
(22,898
|
)
|
|
$
|
13,416
|
|
|
$
|
(23,006
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heckmann Corporation and Subsidiaries
Condensed Consolidating Statement of Operations
For the Year Ended December 31, 2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(dollars in thousands)
|
|
Heckmann
Corp.
(Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Revenue
|
|
$
|
|
|
|
$
|
15,208
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
15,208
|
|
Cost of sales
|
|
|
|
|
|
|
(11,337
|
)
|
|
|
|
|
|
|
|
|
|
|
(11,337
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
|
|
|
|
3,871
|
|
|
|
|
|
|
|
|
|
|
|
3,871
|
|
Operating expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
General and administrative expenses
|
|
|
8,477
|
|
|
|
3,077
|
|
|
|
|
|
|
|
|
|
|
|
11,554
|
|
Pipeline start-up and commissioning
|
|
|
|
|
|
|
11,830
|
|
|
|
|
|
|
|
|
|
|
|
11,830
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating expenses
|
|
|
8,477
|
|
|
|
14,907
|
|
|
|
|
|
|
|
|
|
|
|
23,384
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (Loss) from operations
|
|
|
(8,477
|
)
|
|
|
(11,036
|
)
|
|
|
|
|
|
|
|
|
|
|
(19,513
|
)
|
Interest income (expense), net
|
|
|
2,580
|
|
|
|
(493
|
)
|
|
|
|
|
|
|
|
|
|
|
2,087
|
|
Loss from equity investment
|
|
|
(8,012
|
)
|
|
|
(689
|
)
|
|
|
|
|
|
|
8,012
|
|
|
|
(689
|
)
|
Other, net
|
|
|
205
|
|
|
|
4,206
|
|
|
|
|
|
|
|
|
|
|
|
4,411
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations before income taxes
|
|
|
(13,704
|
)
|
|
|
(8,012
|
)
|
|
|
|
|
|
|
8,012
|
|
|
|
(13,704
|
)
|
Income tax benefit
|
|
|
3,404
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,404
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from continuing operations
|
|
|
(10,300
|
)
|
|
|
(8,012
|
)
|
|
|
|
|
|
|
8,012
|
|
|
|
(10,300
|
)
|
Loss from discontinued operations, net of income taxes
|
|
|
(4,393
|
)
|
|
|
|
|
|
|
(4,393
|
)
|
|
|
4,393
|
|
|
|
(4,393
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss attributable to common stockholders
|
|
$
|
(14,693
|
)
|
|
$
|
(8,012
|
)
|
|
$
|
(4,393
|
)
|
|
$
|
12,405
|
|
|
$
|
(14,693
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heckmann Corporation and Subsidiaries
Condensed Consolidating Statement of Cash Flows
For the Year Ended December 31, 2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(dollars in thousands)
|
|
Heckmann
Corp. (Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
AWS
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Operating activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) income
|
|
$
|
2,527
|
|
|
$
|
(10,116
|
)
|
|
$
|
158
|
|
|
$
|
9,958
|
|
|
$
|
2,527
|
|
Depreciation and amortization
|
|
|
4
|
|
|
|
58,005
|
|
|
|
526
|
|
|
|
|
|
|
|
58,535
|
|
Other adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities
|
|
|
8,964
|
|
|
|
(47,324
|
)
|
|
|
252
|
|
|
|
|
|
|
|
(38,108
|
)
|
Changes in operating assets and liabilities, net of acquisitions and purchase price adjustments
|
|
|
(34,614
|
)
|
|
|
52,329
|
|
|
|
(40
|
)
|
|
|
(9,958
|
)
|
|
|
7,717
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash (used in) provided by operating activities from continuing operations
|
|
|
(23,119
|
)
|
|
|
52,894
|
|
|
|
896
|
|
|
|
|
|
|
|
30,671
|
|
Investing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for acquisitions, net of cash acquired
|
|
|
(359,456
|
)
|
|
|
(15
|
)
|
|
|
|
|
|
|
|
|
|
|
(359,471
|
)
|
Purchase of property, plant and equipment
|
|
|
(41
|
)
|
|
|
(45,504
|
)
|
|
|
(9
|
)
|
|
|
|
|
|
|
(45,554
|
)
|
Proceeds from available for sale securities
|
|
|
5,169
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,169
|
|
Proceeds from the sale of property and equipment
|
|
|
|
|
|
|
7,240
|
|
|
|
|
|
|
|
|
|
|
|
7,240
|
|
Other
|
|
|
|
|
|
|
(51
|
)
|
|
|
(31
|
)
|
|
|
|
|
|
|
(82
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities from continuing operations
|
|
|
(354,328
|
)
|
|
|
(38,330
|
)
|
|
|
(40
|
)
|
|
|
|
|
|
|
(392,698
|
)
|
Financing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from issuance of the 2018 Notes
|
|
|
398,980
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
398,980
|
|
Proceeds from equity offering
|
|
|
76,048
|
|
|
|
(1,600
|
)
|
|
|
|
|
|
|
|
|
|
|
74,448
|
|
Repayment of old credit facility
|
|
|
(140,174
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(140,174
|
)
|
Payment of deferred financing costs
|
|
|
(26,170
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(26,170
|
)
|
Proceeds from revolving credit facility
|
|
|
146,990
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
146,990
|
|
Payments on acquired debt
|
|
|
(150,367
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(150,367
|
)
|
Payments on other debt
|
|
|
|
|
|
|
(4,605
|
)
|
|
|
|
|
|
|
|
|
|
|
(4,605
|
)
|
Other
|
|
|
(1,569
|
)
|
|
|
511
|
|
|
|
|
|
|
|
|
|
|
|
(1,058
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing activities from continuing operations
|
|
|
303,738
|
|
|
|
(5,694
|
)
|
|
|
|
|
|
|
|
|
|
|
298,044
|
|
Net (decrease) increase in cash
|
|
|
(73,709
|
)
|
|
|
8,870
|
|
|
|
856
|
|
|
|
|
|
|
|
(63,983
|
)
|
Cash and cash equivalents - beginning of period
|
|
|
79,528
|
|
|
|
666
|
|
|
|
|
|
|
|
|
|
|
|
80,194
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents - end of period
|
|
$
|
5,819
|
|
|
$
|
9,536
|
|
|
$
|
856
|
|
|
$
|
|
|
|
$
|
16,211
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heckmann Corporation and Subsidiaries
Condensed Consolidating Statement of Cash Flows
For the Year Ended December 31, 2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31, 2011
|
|
(dollars in thousands)
|
|
Heckmann
Corp. (Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
Non-Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Operating activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
(23,006
|
)
|
|
$
|
9,482
|
|
|
$
|
(22,898
|
)
|
|
$
|
13,416
|
|
|
$
|
(23,006
|
)
|
Loss from discontinued operations
|
|
|
22,898
|
|
|
|
|
|
|
|
22,898
|
|
|
|
(22,898
|
)
|
|
|
22,898
|
|
Depreciation and amortization
|
|
|
34
|
|
|
|
25,247
|
|
|
|
|
|
|
|
|
|
|
|
25,281
|
|
Other adjustments to reconcile net loss to net cash used in operating activities
|
|
|
2,253
|
|
|
|
(7,600
|
)
|
|
|
|
|
|
|
|
|
|
|
(5,347
|
)
|
Changes in operating assets and liabilities, net of acquisitions and purchase price adjustments
|
|
|
(160,863
|
)
|
|
|
122,276
|
|
|
|
|
|
|
|
9,482
|
|
|
|
(29,105
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in operating activities from continuing operations
|
|
|
(158,684
|
)
|
|
|
149,405
|
|
|
|
|
|
|
|
|
|
|
|
(9,279
|
)
|
Net cash used in operating activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(4,683
|
)
|
|
|
|
|
|
|
(4,683
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in operating activities
|
|
|
(158,684
|
)
|
|
|
149,405
|
|
|
|
(4,683
|
)
|
|
|
|
|
|
|
(13,962
|
)
|
Investing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for acquisitions, net of cash acquired
|
|
|
(88,544
|
)
|
|
|
210
|
|
|
|
|
|
|
|
|
|
|
|
(88,334
|
)
|
Purchase or property, plant and equipment
|
|
|
(299
|
)
|
|
|
(150,622
|
)
|
|
|
|
|
|
|
|
|
|
|
(150,921
|
)
|
Purchases of available for sale securities
|
|
|
(34,947
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(34,947
|
)
|
Proceeds from the sale of available for sale securities
|
|
|
120,062
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
120,062
|
|
Proceeds from the sale of certificates of deposit
|
|
|
11,830
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
11,830
|
|
Investment in joint venture
|
|
|
(16
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(16
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities from continuing operations
|
|
|
8,086
|
|
|
|
(150,412
|
)
|
|
|
|
|
|
|
|
|
|
|
(142,326
|
)
|
Net cash used in investing activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(5,777
|
)
|
|
|
|
|
|
|
(5,777
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
8,086
|
|
|
|
(150,412
|
)
|
|
|
(5,777
|
)
|
|
|
|
|
|
|
(148,103
|
)
|
Financing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments on long term debt agreements
|
|
|
(73,914
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(73,914
|
)
|
Borrowings under revolving credit facility
|
|
|
72,799
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
72,799
|
|
Borrowings under term loan
|
|
|
109,885
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
109,885
|
|
Payment of deferred financing costs
|
|
|
(2,764
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,764
|
)
|
Cash proceeds from the exercise of warrants
|
|
|
47,912
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
47,912
|
|
Cash paid to purchase treasury stock
|
|
|
(4,414
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,414
|
)
|
Proceeds from notes payable and other
|
|
|
1,488
|
|
|
|
55
|
|
|
|
|
|
|
|
|
|
|
|
1,543
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities from continuing operations
|
|
|
150,992
|
|
|
|
55
|
|
|
|
|
|
|
|
|
|
|
|
151,047
|
|
Net cash provided by financing activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
150,992
|
|
|
|
55
|
|
|
|
|
|
|
|
|
|
|
|
151,047
|
|
Net decrease in cash
|
|
|
394
|
|
|
|
(952
|
)
|
|
|
(10,460
|
)
|
|
|
|
|
|
|
(11,018
|
)
|
Cash and cash equivalentsbeginning of period
|
|
|
79,134
|
|
|
|
1,618
|
|
|
|
10,460
|
|
|
|
|
|
|
|
91,212
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalentsend of period
|
|
|
79,528
|
|
|
|
666
|
|
|
|
|
|
|
|
|
|
|
|
80,194
|
|
Less: cash and cash equivalents of discontinued operations at year end
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents of continuing operations at year-end
|
|
$
|
79,528
|
|
|
$
|
666
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
80,194
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heckmann Corporation and Subsidiaries
Condensed Consolidating Statement of Cash Flows
For the Year Ended
December 31, 2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31, 2010
|
|
(dollars in thousands)
|
|
Heckmann
Corp.
(Parent)
|
|
|
Subsidiary
Guarantors
|
|
|
Non-
Guarantor
Subsidiary
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Operating activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$
|
(14,693
|
)
|
|
$
|
(8,012
|
)
|
|
$
|
(4,393
|
)
|
|
$
|
12,405
|
|
|
$
|
(14,693
|
)
|
Loss from discontinued operations
|
|
|
4,393
|
|
|
|
|
|
|
|
4,393
|
|
|
|
(4,393
|
)
|
|
|
4,393
|
|
Depreciation and amortization
|
|
|
|
|
|
|
4,605
|
|
|
|
|
|
|
|
|
|
|
|
4,605
|
|
Other adjustments to reconcile net loss to net cash used in operating activities
|
|
|
966
|
|
|
|
(2,200
|
)
|
|
|
|
|
|
|
|
|
|
|
(1,234
|
)
|
Changes in operating assets and liabilities, net of acquisitions and purchase price adjustments
|
|
|
6,172
|
|
|
|
5,416
|
|
|
|
|
|
|
|
(8,012
|
)
|
|
|
3,576
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in operating activities from continuing operations
|
|
|
(3,162
|
)
|
|
|
(191
|
)
|
|
|
|
|
|
|
|
|
|
|
(3,353
|
)
|
Net cash used in operating activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(749
|
)
|
|
|
|
|
|
|
(749
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in operating activities
|
|
|
(3,162
|
)
|
|
|
(191
|
)
|
|
|
(749
|
)
|
|
|
|
|
|
|
(4,102
|
)
|
Investing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for acquisitions, net of cash acquired
|
|
|
(28,635
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(28,635
|
)
|
Purchase or property, plant and equipment
|
|
|
|
|
|
|
(17,443
|
)
|
|
|
|
|
|
|
|
|
|
|
(17,443
|
)
|
Proceeds from available for sale securities
|
|
|
168,392
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
168,392
|
|
Purchase of available for sale securities
|
|
|
(157,478
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(157,478
|
)
|
Purchase of certificates of deposit
|
|
|
(1,367
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,367
|
)
|
Other
|
|
|
(1,135
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,135
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities from continuing operations
|
|
|
(20,223
|
)
|
|
|
(17,443
|
)
|
|
|
|
|
|
|
|
|
|
|
(37,666
|
)
|
Net cash used in investing activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(537
|
)
|
|
|
|
|
|
|
(537
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(20,223
|
)
|
|
|
(17,443
|
)
|
|
|
(537
|
)
|
|
|
|
|
|
|
(38,203
|
)
|
Financing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments on long term debt agreements
|
|
|
(193
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(193
|
)
|
Cash paid to repurchase warrants
|
|
|
(2,034
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,034
|
)
|
Cash proceeds from the exercise of warrants
|
|
|
66
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
66
|
|
Cash proceeds from the exercise of stock options
|
|
|
194
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
194
|
|
Cash paid to purchase treasury stock
|
|
|
(1,088
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,088
|
)
|
Proceeds from notes payable
|
|
|
1,418
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,418
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities from continuing operations
|
|
|
(1,637
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,637
|
)
|
Net cash provided by financing activities from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(992
|
)
|
|
|
|
|
|
|
(992
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
(1,637
|
)
|
|
|
|
|
|
|
(992
|
)
|
|
|
|
|
|
|
(2,629
|
)
|
Net decrease in cash
|
|
|
(25,022
|
)
|
|
|
(17,634
|
)
|
|
|
(2,278
|
)
|
|
|
|
|
|
|
(44,934
|
)
|
Cash and cash equivalents - beginning of period
|
|
|
104,060
|
|
|
|
19,252
|
|
|
|
12,738
|
|
|
|
|
|
|
|
136,050
|
|
Effect of change in foreign exchange rate on cash and cash equivalents
|
|
|
96
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
96
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents - end of period
|
|
|
79,134
|
|
|
|
1,618
|
|
|
|
10,460
|
|
|
|
|
|
|
|
91,212
|
|
Less: cash and cash equivalents of discontinued operations at year end
|
|
|
|
|
|
|
|
|
|
|
(10,460
|
)
|
|
|
|
|
|
|
(10,460
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents of continuing operations at year-end
|
|
$
|
79,134
|
|
|
$
|
1,618
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
80,752
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(18) Discontinued Operations
On September 30, 2011, the Company, through its wholly-owned subsidiary, China Water, entered into a Share
Purchase Agreement (the SPA) by and among Pacific Water & Drinks (HK) Group Limited (f/k/a Sino Bloom Investments Limited), a Hong Kong company (Buyer), China Water, as Seller, and China Water Drinks (H.K.) Holdings
Limited, a Hong Kong company (Target), pursuant to which China Water agreed to sell 100% of the equity interests in Target to Buyer in exchange for shares in Buyer equal to ten percent of the Buyers outstanding equity. Upon
completion of the sale, the Company abandoned the remaining non-U.S. legal entities that were part of its original acquisition of China Water. The following table details selected financial information of discontinued operations (in 000s):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31,
|
|
|
|
2012
|
|
|
2011
|
|
|
2010
|
|
Revenue
|
|
$
|
|
|
|
$
|
20,560
|
|
|
$
|
30,483
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pretax loss from operations
|
|
|
|
|
|
|
(4,881
|
)
|
|
|
(4,048
|
)
|
Income tax expense
|
|
|
|
|
|
|
(100
|
)
|
|
|
(345
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from operations
|
|
|
|
|
|
|
(4,981
|
)
|
|
|
(4,393
|
)
|
Loss from disposal, net of tax $0
|
|
|
|
|
|
|
(17,917
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss from discontinued operations
|
|
$
|
|
|
|
$
|
(22,898
|
)
|
|
$
|
(4,393
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(19)
|
Selected Unaudited Quarterly Financial Data (in 000s, except per share amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months ended
|
|
|
|
March 31
|
|
|
June 30
|
|
|
September 30
|
|
|
December 31
|
|
2012
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$
|
54,959
|
|
|
$
|
90,769
|
|
|
$
|
93,050
|
|
|
$
|
113,205
|
|
Gross profit
|
|
|
6,986
|
|
|
|
15,059
|
|
|
|
16,417
|
|
|
|
7,865
|
|
Income (loss) from continuing operations (2) (3)
|
|
|
(3,863
|
)
|
|
|
10,743
|
|
|
|
(9,345
|
)
|
|
|
4,992
|
|
Net Income (loss) attributable to common stockholders (2) (3)
|
|
|
(3,863
|
)
|
|
|
10,743
|
|
|
|
(9,345
|
)
|
|
|
4,992
|
|
Income (loss) per common share from continuing operations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
(0.03
|
)
|
|
|
0.07
|
|
|
|
(0.06
|
)
|
|
|
0.03
|
|
Diluted
|
|
|
(0.03
|
)
|
|
|
0.07
|
|
|
|
(0.06
|
)
|
|
|
0.03
|
|
Income (loss) per common share from discontinued operations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
(0.03
|
)
|
|
|
0.07
|
|
|
|
(0.06
|
)
|
|
|
0.03
|
|
Diluted
|
|
|
(0.03
|
)
|
|
|
0.07
|
|
|
|
(0.06
|
)
|
|
|
0.03
|
|
(1)
|
Totals may not equal corresponding amounts on the Consolidated Statements of Operations due to rounding.
|
F-36
(2)
|
During the fourth quarter of 2012, the following recorded the following unusual or non-recurring items:
|
|
(a)
|
The Company released $17.8 million of valuation allowance associated with NOLs because of a determination that the realization of the associated deferred tax
assets is more likely that not based on future taxable income arising from the reversal of deferred tax liabilities that the Company acquired in connection with the Power Fuels merger.
|
|
(b)
|
The Company recognized an impairment of long-lived assets of $3.7 million for the write-down of the carrying values of three saltwater disposal wells.
|
|
(c)
|
The Company recognized an impairment of intangible assets of $2.4 million for the write-down of a customer relationship intangible associated with a portion of a prior
business acquisition.
|
|
(d)
|
The Company recorded a $1.4 million environmental accrual for the estimated costs necessary to comply with a Louisiana Department of Environmental Quality requirement
that the Company test and monitor the soil at certain locations to confirm that prior saltwater spills were successfully remediated.
|
(3)
|
During the second quarter of 2012, the Company released $20.7 million of valuation allowance associated with NOLs because of a determination that the
realization of the associated deferred tax assets is more likely than not based on future taxable income arising from the reversal of deferred tax liabilities that the Company acquired in connection with the TFI acquisition.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months ended
|
|
|
|
March 31
|
|
|
June 30
|
|
|
September 30
|
|
|
December 31
|
|
2011
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$
|
18,231
|
|
|
$
|
39,167
|
|
|
$
|
47,768
|
|
|
$
|
51,671
|
|
Gross profit
|
|
|
4,410
|
|
|
|
10,112
|
|
|
|
11,978
|
|
|
|
6,828
|
|
Income (loss) from continuing operations
|
|
|
(539
|
)
|
|
|
317
|
|
|
|
2,594
|
|
|
|
(2,480
|
)
|
Income (loss) from discontinued operations
|
|
|
904
|
|
|
|
(134
|
)
|
|
|
(23,668
|
)
|
|
|
|
|
Net Income (loss) attributable to common stockholders
|
|
|
365
|
|
|
|
183
|
|
|
|
(21,074
|
)
|
|
|
(2,480
|
)
|
Income (loss) per common share from continuing operations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
*
|
|
|
|
*
|
|
|
|
0.02
|
|
|
|
(0.02
|
)
|
Diluted
|
|
|
*
|
|
|
|
*
|
|
|
|
0.02
|
|
|
|
(0.02
|
)
|
Income (loss) per common share from discontinued operations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
0.01
|
|
|
|
*
|
|
|
|
(0.21
|
)
|
|
|
*
|
|
Diluted
|
|
|
0.01
|
|
|
|
*
|
|
|
|
(0.21
|
)
|
|
|
*
|
|
Total:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
*
|
|
|
|
*
|
|
|
|
(0.19
|
)
|
|
|
(0.02
|
)
|
Diluted
|
|
|
*
|
|
|
|
*
|
|
|
|
(0.19
|
)
|
|
|
(0.02
|
)
|
*
|
Amount is less than $0.01.
|
(1)
|
Totals may not equal corresponding amounts on the Consolidated Statements of Operations due to rounding.
|
Diluted net income (loss) per common share for each of the quarters presented above is based on the respective weighted average number of
common shares outstanding for each quarter and the sum of the quarters may not necessarily be equal to the full year diluted net loss per common share amounts.
F-37