FALSE000138419500013841952024-03-072024-03-07
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_____________________________________________________________________________________________________________________________________________________________________________
FORM 8-K
_____________________________________________________________________________________________________________________________________________________________________________
CURRENT REPORT
Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
Date of Report: March 7, 2024
(Date of earliest event reported)
______________________________________________________________________________________
RING ENERGY, INC.
(Exact name of registrant as specified in its charter)
_______________________________________________________________________________________________________
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Nevada | | 001-36057 | | 90-0406406 |
(State or other jurisdiction of incorporation) | | (Commission File Number) | | (IRS Employer Identification No.) |
1725 Hughes Landing Blvd., Suite 900
The Woodlands, TX 77380
(Address of principal executive offices) (Zip Code)
(281) 397-3699
(Registrant’s telephone number, including area code)
Not Applicable.
(Former name or former address, if changed since last report)
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions: | | | | | | | | |
| ☐ | Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) |
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| ☐ | Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) |
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| ☐ | Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) |
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| ☐ | Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) |
Securities registered pursuant to Section 12(b) of the Act: | | | | | | | | |
Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
Common Stock, $0.001 par value | REI | NYSE American |
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
Emerging growth company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Item 2.02 Results of Operations and Financial Condition.
On March 7, 2024, Ring Energy, Inc. (the “Company”) issued a press release announcing its financial and operating results for the fourth quarter and year ended December 31, 2023. A copy of the press release is furnished herewith as Exhibit 99.1.
The information in this Current Report on Form 8-K furnished pursuant to Item 2.02, including Exhibit 99.1, shall not be deemed to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to liability under that section, and they shall not be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended (the “Securities Act”), or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.
Item 7.01 Regulation FD Disclosure.
On March 8, 2024, the Company posted to its website a company presentation (the “Presentation Materials”) that management intends to use from time to time. The Company may use the Presentation Materials, possibly with modifications, in presentations to current and potential investors, lenders, creditors, vendors, customers and others with an interest in the Company and its business.
The information contained in the Presentation Materials is summary information that should be considered in the context of the Company’s filings with the Securities and Exchange Commission and other public announcements that the Company may make by press release or otherwise from time to time. The Presentation Materials speak as of the date of this Current Report on Form 8-K. While the Company may elect to update the Presentation Materials in the future or reflect events and circumstances occurring or existing after the date of this Current Report on Form 8-K, the Company specifically disclaims any obligation to do so. The Presentation Materials are furnished herewith as Exhibit 99.2 to this Current Report on Form 8-K and are incorporated herein by reference.
The information in this Current Report on Form 8-K furnished pursuant to Item 7.01, including Exhibit 99.2, shall not be deemed to be “filed” for the purposes of Section 18 of the Exchange Act, or otherwise subject to liability under that section, and they shall not be deemed incorporated by reference in any filing under the Securities Act or the Exchange Act, except as shall be expressly set forth by specific reference in such filing. By filing this Current Report on Form 8-K and furnishing this information pursuant to Item 7.01, the Company makes no admission as to the materiality of any information in this Current Report on Form 8-K, including Exhibit 99.2, that is required to be disclosed solely by Regulation FD.
Item 9.01 Financial Statements and Exhibits.
(d) Exhibits.
The following exhibits are included with this Current Report on Form 8-K:
| | | | | | | | | | | |
Exhibit No. | | Description |
| 99.1 | | |
| 99.2 | | |
| 104 | | Cover Page Interactive Data File (embedded within the Inline XBRL document). |
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
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| | RING ENERGY, INC.
|
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Date: | March 8, 2024 | By: | /s/ Travis T. Thomas |
| | | Travis T. Thomas |
| | | Chief Financial Officer |
RING ENERGY ANNOUNCES RECORD FOURTH QUARTER AND FULL YEAR 2023 RESULTS, YEAR-END 2023 PROVED RESERVES AND ADDITIONAL 2024 GUIDANCE
The Woodlands, TX – March 7, 2024 – Ring Energy, Inc. (NYSE American: REI) (“Ring” or the “Company”) today reported record operational and financial results for the fourth quarter and full year 2023, year-end 2023 proved reserves and provided additional 2024 operational and financial guidance.
2023 Q4 and Full Year Highlights and Recent Key Items
•Grew fourth quarter total sales volumes 11% to a record 19,397 barrels of oil equivalent per day (“Boe/d”) from the third quarter;
◦Increased fourth quarter oil sales volumes 13% to a record 13,637 barrels of oil per day (“Bo/d”) from the third quarter;
•Increased year-over-year total sales volumes by 47% to a record 18,119 Boe/d;
◦Grew full year oil sales volumes by 32% to a record 12,548 Bo/d from 2022;
•Reported net income of $50.9 million, or $0.26 per diluted share, in the fourth quarter;
◦Net income for the full year was $104.9 million, or $0.54 per diluted share;
•Generated fourth quarter Adjusted Net Income1 of $21.2 million, or $0.11 per diluted share;
◦Full year Adjusted Net Income was $100.5 million, or $0.51 per diluted share;
•Reduced all-in fourth quarter cash operating costs1 on a Boe basis by 4% from the third quarter, and a 6% decrease for the full year;
•Achieved record fourth quarter Adjusted EBITDA1 of $65.4 million — 12% higher than the third quarter;
◦Grew year-over-year Adjusted EBITDA by 21% to a record $236.0 million;
•Delivered record Adjusted Free Cash Flow1 of $16.3 million and Adjusted Cash Flow from Operations1 of $55.1 million in the fourth quarter;
◦Cash flow positive for the 17th consecutive quarter;
◦Full year Adjusted Free Cash Flow grew 30% to $45.3 million while generating Adjusted Cash Flow from Operations of $197.0 million — a 14% increase;
•Generated a Cash Return on Capital Employed (“CROCE”)1 of 17.2% in 2023;
•Paid down $3.0 million of debt during the fourth quarter and $30.0 million since closing the Founders Acquisition in August 2023;
◦Entered 2024 with liquidity of approximately $175 million;
◦Exited 2023 with $425 million of borrowings and a Leverage Ratio2 of 1.62x;
•Ended 2023 with proved reserves of 129.8 million barrels of oil equivalent (“MMBoe”) and a present value discounted at 10% (“PV-10”)1 of $1.6 billion, using Securities and Exchange Commission (“SEC”) pricing;
◦Proved developed reserves were 88.1 MMBoe with a PV-10 of $1.3 billion ; and
•Successfully completed the Company’s 2023 full year capital spending program, including drilling and placing online 20 horizontal (“Hz”) and 11 vertical wells.
Mr. Paul D. McKinney, Chairman of the Board and Chief Executive Officer, commented, “We ended 2023 with record fourth quarter and full year operational and financial results on multiple fronts. Year-over-year, we achieved a 47% increase in sales volumes, a 21% increase in Adjusted EBITDA, and a 30% increase in Adjusted Free Cash Flow. Driving our results was the successful execution and integration of the two acquisitions made over the past 18 months, the success of our
1A non-GAAP financial measure; see “Non-GAAP Information” section in this release for more information including reconciliations to the most comparable GAAP measures.
2 Refer to the “Non-GAAP Information” section in this release for calculation of the Leverage Ratio based on our Credit Agreement.
high rate-of-return drilling and recompletion programs, and our continuing focus on reducing costs. The hard work, dedication, and commitment of our workforce to our value focused, proven strategy delivered these outstanding results and we continue to believe staying the course will build near and long-term value for our stockholders. On behalf of our Board of Directors and management team, I would like to thank our employees for their efforts in making 2023 a very good year.’’
Mr. McKinney continued, “Our focus for 2024 will be very similar to the past. We will continue a disciplined capital spending program designed to organically maintain or slightly grow our oil production with the flexibility to respond as necessary to changing oil and natural gas prices. We intend to allocate our excess cash from operations to reducing debt and improving our balance sheet. We plan to continue seeking to grow through our pursuit of accretive, balance sheet enhancing acquisitions. These efforts should lead us to our ultimate goal, which is to further position our balance sheet and achieve the size and scale necessary to sustainably return meaningful capital to our stockholders. We believe our efforts in 2024 will make important strides towards achieving these goals. We also want to thank our stockholders for their trust and support as we pursue the opportunities and navigate the challenges the future may present.”
Summary Results
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Q4 2023 | Q3 2023 | Q4 to Q3 2023 % Change | Q4 2022 | Q4 YOY % Change | FY 2023 | FY 2022 | FY % Change |
| Net Sales (Boe/d) | 19,397 | 17,509 | 11% | 17,856 | 9% | 18,119 | 12,364 | 47% |
| Crude Oil (Bo/d) | 13,637 | 12,028 | 13% | 12,189 | 12% | 12,548 | 9,479 | 32% |
| Net Sales (MBoe) | 1,784.5 | 1,610.9 | 11% | 1,642.7 | 9% | 6,613.3 | 4,512.6 | 47% |
| Realized Price - All Products ($/Boe) | $56.01 | $58.16 | (4)% | $60.69 | (8)% | $54.60 | $76.95 | (29)% |
| Revenues ($MM) | $99.9 | $93.7 | 7% | $99.7 | —% | $361.1 | $347.2 | 4% |
| Net Income/Loss ($MM) | $50.9 | $(7.5) | NM | $14.5 | 251% | $104.9 | $138.6 | (24)% |
| Adjusted Net Income ($MM) | $21.2 | $26.3 | (19)% | $21.8 | (3)% | $100.5 | $107.5 | (7)% |
| Adjusted EBITDA ($MM) | $65.4 | $58.6 | 12% | $56.3 | 16% | $236.0 | $195.2 | 21% |
| Capital Expenditures ($MM) | $38.8 | $42.4 | (8)% | $42.6 | (9)% | $152.0 | $140.1 | 9% |
| Adjusted Free Cash Flow ($MM) | $16.3 | $6.1 | 165% | $5.5 | 197% | $45.3 | $34.8 | 30% |
Financial Overview: For the fourth quarter of 2023, the Company reported net income of $50.9 million, or $0.26 per diluted share, which included a $32.5 million before tax non-cash unrealized commodity derivative gain, $2.5 million in before tax share-based compensation and $0.4 million in before tax transaction related costs for executed acquisitions and divestitures (“Transaction Costs”). Excluding the estimated after-tax impact of the adjustments, the Company’s Adjusted Net Income was $21.2 million, or $0.11 per diluted share.
In the third quarter of 2023, the Company reported a net loss of $(7.5) million, or $(0.04) per diluted share, which included a $33.9 million before tax non-cash unrealized commodity derivative loss, $2.2 million for before tax share-based compensation, and $(0.2) million in before tax Transaction Costs. Excluding the estimated after-tax impact of these adjustments, the Company’s Adjusted Net Income was $26.3 million, or $0.13 per diluted share.
In the fourth quarter of 2022, Ring reported net income of $14.5 million, or $0.08 per diluted share, which included a $5.4 million before tax non-cash unrealized commodity derivative loss, $2.2 million in before tax share-based compensation, and $1.0 million in before tax Transaction Costs. Excluding the estimated after-tax impact of these adjustments, Adjusted Net Income in the fourth quarter of 2022 was $21.8 million, or $0.12 per diluted share.
Adjusted EBITDA was a record $65.4 million for the fourth quarter of 2023, a 12% increase from $58.6 million for the third quarter of 2023, and a 16% increase from fourth quarter of 2022 Adjusted EBITDA of $56.3 million.
Adjusted Free Cash Flow for the fourth quarter of 2023 was a record $16.3 million compared to $6.1 million in the third quarter of 2023 with the 165% increase primarily due to increased revenues and lower capital spending in the fourth quarter. Fourth quarter 2023 Adjusted Free Cash Flow increased 197% from $5.5 million for the fourth quarter of 2022.
Adjusted Cash Flow from Operations was a record $55.1 million for the fourth quarter of 2023 compared to $48.5 million for the third quarter of 2023 and $47.4 million for the fourth quarter of 2022.
Adjusted Net Income, Adjusted EBITDA, Adjusted Free Cash Flow, Adjusted Cash Flow from Operations, Cash Return on Capital Employed and PV-10 are non-GAAP financial measures, which are described in more detail and reconciled to the most comparable GAAP measures, in the tables shown later in this release under “Non-GAAP Information.”
Sales Volumes, Prices and Revenues: Sales volumes for the fourth quarter of 2023 were 19,397 Boe/d (70% oil, 15% natural gas and 15% natural gas liquids (”NGLs”)), or 1,784,490 Boe, compared to 17,509 Boe/d (69% oil, 16% natural gas and 15% NGLs), or 1,610,857 Boe, for the third quarter of 2023, and 17,856 Boe/d (68% oil, 17% natural gas and 15% NGLs), or 1,642,715 Boe, in the fourth quarter of 2022. Fourth quarter 2023 sales volumes were near the high end of the Company’s guidance of 18,900 to 19,500 Boe/d. Fourth quarter 2023 sales volumes were comprised of 1,254,619 barrels (“Bbls”) of oil, 1,613,102 thousand cubic feet (“Mcf”) of natural gas and 261,020 Bbls of NGLs.
For the fourth quarter of 2023, the Company realized an average sales price of $77.33 per barrel of crude oil, $(0.12) per Mcf for natural gas and $11.92 per barrel of NGLs. The realized natural gas and NGL prices are impacted by a fee reduction to the value received. For the fourth quarter of 2023, the weighted average natural gas price per Mcf was $1.49 offset by a weighted average fee value per Mcf of ($1.61), and the weighted average NGL price per barrel was $19.99 offset by a weighted average fee of ($8.07) per barrel. The combined average realized sales price for the period was $56.01 per Boe, down 4% versus $58.16 per Boe for the third quarter of 2023, and down 8% from $60.69 per Boe in the fourth quarter of 2022. The average oil price differential the Company experienced from WTI NYMEX futures pricing in the fourth quarter of 2023 was a negative $0.92 per barrel of crude oil, while the average natural gas price differential from NYMEX futures pricing was a negative $3.12 per Mcf.
Revenues were $99.9 million for the fourth quarter of 2023 compared to $93.7 million for the third quarter of 2023 and $99.7 million for the fourth quarter of 2022. The 7% increase in fourth quarter 2023 revenues from the third quarter was driven by higher sales volumes partially offset by lower overall realized pricing.
Lease Operating Expense (“LOE”): LOE, which includes expensed workovers and facilities maintenance, was $18.7 million, or $10.50 per Boe, in the fourth quarter of 2023 versus $18.0 million, or $11.18 per Boe, in the third quarter of 2023 and $17.4 million, or $10.60 per Boe, for the fourth quarter of 2022. Fourth quarter 2023 LOE came in at the low end of the Company’s guidance range of $10.50 to $11.00 per Boe and Ring remains focused on driving continued efficiencies throughout its operations.
Gathering, Transportation and Processing (“GTP”) Costs: As previously disclosed, due to a contractual change effective May 1, 2022, the Company no longer maintains ownership and control of the majority of of its natural gas through processing. As a result, GTP costs are now
reflected as a reduction to the natural gas sales price and not as an expense item. There remains only one contract in place with a natural gas processing entity where the point of control of gas dictates requiring the fees to be recorded as an expense.
Ad Valorem Taxes: Ad valorem taxes were $0.92 per Boe for the fourth quarter of 2023 compared to $1.10 per Boe in the third quarter of 2023 and $0.96 per Boe for the fourth quarter of 2022.
Production Taxes: Production taxes were $2.78 per Boe in the fourth quarter of 2023 compared to $2.95 per Boe in the third quarter of 2023 and $3.16 per Boe in fourth quarter of 2022. Production taxes ranged between 5.0% to 5.2% of revenue for all three periods.
Depreciation, Depletion and Amortization (“DD&A”) and Asset Retirement Obligation Accretion: DD&A was $13.76 per Boe in the fourth quarter of 2023 versus $13.65 per Boe for the third quarter of 2023 and $12.71 per Boe in the fourth quarter of 2022. Asset retirement obligation accretion was $0.20 per Boe in the fourth quarter of 2023 compared to $0.22 per Boe for the third quarter of 2023 and fourth quarter of 2022.
General and Administrative Expenses (“G&A”): G&A was $8.2 million ($4.58 per Boe) for the fourth quarter of 2023 versus $7.1 million ($4.40 per Boe) for the third quarter of 2023 and $8.3 million ($5.08 per Boe) in the fourth quarter of 2022. G&A, excluding share-based compensation1, was $5.7 million for the fourth quarter of 2023 ($3.20 per Boe) versus $4.9 million for the third quarter of 2023 ($3.05 per Boe) and $6.1 million in the fourth quarter of 2022 ($3.74 per Boe). The fourth quarter and third quarter of 2023 included Transaction Costs of $0.4 million and $(0.2) million, respectively. Adjusting for Transaction Costs, fourth quarter 2023 G&A, excluding share-based compensation, was $3.00 per Boe compared to $3.15 per Boe for the third quarter of 2023 — a 5% decrease.
Interest Expense: Interest expense was $11.6 million in the fourth quarter of 2023 versus $11.4 million for the third quarter of 2023 and $9.5 million for the fourth quarter of 2022.
Derivative (Loss) Gain: In the fourth quarter of 2023, Ring recorded a net gain of $29.3 million on its commodity derivative contracts, including a realized $3.3 million cash commodity derivative loss and an unrealized $32.5 million non-cash commodity derivative gain. This compared to a net loss of $39.2 million in the third quarter of 2023, including a realized $5.4 million cash commodity derivative loss and an unrealized $33.9 million non-cash commodity derivative loss, and a net loss of $19.3 million in the fourth quarter of 2022, including a realized
$13.9 million cash commodity derivative loss and an unrealized $5.4 million non-cash commodity derivative loss.
A summary listing of the Company’s outstanding derivative positions at December 31, 2023 is included in the tables shown later in this release. A quarterly breakout is provided in the Company’s investor presentation.
For full year 2024, the Company currently has approximately 2.1 million barrels of oil (45% of oil sales guidance midpoint) hedged and 2.6 billion cubic feet of natural gas (43% of natural gas sales guidance midpoint) hedged.
Income Tax: The Company recorded a non-cash income tax provision of $7.9 million in the fourth quarter of 2023 versus a non-cash income tax benefit of $3.4 million in the third quarter of 2023 and a non-cash income tax provision of $2.5 million for the fourth quarter of 2022.
Balance Sheet and Liquidity: Total liquidity at the end of the fourth quarter of 2023 was $174.5 million, a 2% increase from September 30, 2023 and a 7% decrease from December 31, 2022. Liquidity at December 31, 2023 consisted of cash and cash equivalents of $0.3 million and $174.2 million of availability under Ring’s revolving credit facility, which includes a reduction of $0.8 million for letters of credit. On December 31, 2023, the Company had $425.0 million in borrowings outstanding on its revolving credit facility that has a current borrowing base of $600.0 million. Ring paid down $3 million of debt during the fourth quarter of 2023 and $30.0 million since the closing of the Founders Transaction. The Company is targeting further debt pay down during 2024 dependent on market conditions, the timing of capital spending and other considerations.
During the fourth quarter of 2023, Ring successfully reaffirmed the Company’s borrowing base of $600 million under its revolving credit facility. The next regularly scheduled bank redetermination is scheduled to occur during May 2024. Ring is currently in compliance with all applicable covenants under its revolving credit facility.
Capital Expenditures: During the fourth quarter of 2023, capital expenditures on an accrual basis were $38.8 million as compared to Ring’s previous guidance of $35 million to $40 million. The Company drilled four Hz wells (three in the CBP and one in NWS) and three vertical wells in the CBP and completed ten wells (six in the CBP and four in the NWS). Also included in fourth quarter 2023 capital spending were costs for capital workovers, infrastructure upgrades, and leasing costs.
For the year ended December 31, 2023, capital expenditures on an accrual basis were $152.0 million, which included costs to drill, complete and place on production 20 Hz wells (14 in the NWS and six in the CBP) and 11 vertical wells in the CBP. Included in full year 2023 capital spending were costs for capital workovers, infrastructure upgrades, recompletions, and leasing costs. Ring also participated in the drilling and completion of five non-operated wells in the NWS and CBP.
The table below sets forth Ring’s drilling and completions activities by quarter for 2023:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Quarter | | Area | | Wells Drilled | | Wells Completed | | Recompletions |
| | | | | | | | |
| 1Q 2023 | | Northwest Shelf (Horizontal) | | 4 | | 4 | | — |
| | Central Basin Platform (Horizontal) | | — | | — | | — |
| | Central Basin Platform (Vertical) | | 3 | | 3 | | 6 |
| | Total | | 7 | | 7 | | 6 |
| | | | | | | | |
| 2Q 2023 | | Northwest Shelf (Horizontal) | | 4 | | 4 | | — |
| | Central Basin Platform (Horizontal) | | — | | — | | — |
| | Central Basin Platform (Vertical) | | 2 | | 2 | | 3 |
| | Total | | 6 | | 6 | | 3 |
| | | | | | | | |
| 3Q 2023 | | Northwest Shelf (Horizontal) | | 5 | | 2 | | — |
| | Central Basin Platform (Horizontal) | | 3 | | 3 | | — |
| | Central Basin Platform (Vertical) | | 3 | | 3 | | — |
| | Total | | 11 | | 8 | | — |
| | | | | | | | |
| 4Q 2023 | | Northwest Shelf (Horizontal) | | 1 | | 4 | | — |
| | Central Basin Platform (Horizontal) | | 3 | | 3 | | — |
| | Central Basin Platform (Vertical) | | 3 | | 3 | | — |
| | Total (1) | | 7 | | 10 | | — |
| | | | | | | | |
FY 2023 | | Northwest Shelf (Horizontal) | | 14 | | 14 | | — |
| | Central Basin Platform (Horizontal) | | 6 | | 6 | | — |
| | Central Basin Platform (Vertical) | | 11 | | 11 | | 9 |
| | Total (1) | | 31 | | 31 | | 9 |
(1) Fourth quarter total and full year total do not include one SWD well completed in the Northwest Shelf.
Full Year 2023 Summary Financial Review
The Company reported net income for full year 2023 of $104.9 million, or $0.54 per diluted share, and Adjusted Net Income of $100.5 million, or $0.51 per diluted share. For full year 2022,
Ring reported net income of $138.6 million, or $0.98 per diluted share, and Adjusted Net Income of $107.5 million, or $0.76 per diluted share.
In full year 2023, the Company grew Adjusted EBITDA by 21% to a record $236.0 million from $195.2 million in 2022. Ring generated record Adjusted Free Cash Flow for full year 2023 of $45.3 million versus $34.8 million in 2022 — a 30% increase. For full year 2023, the Company grew Adjusted Cash Flow from Operations by 14% to $197.0 million from $172.9 million in 2022.
Revenues totaled $361.1 million for 2023 compared to $347.2 million in 2022, with the 4% increase driven by higher sales volumes partially offset by lower overall realized commodity prices.
Net sales for full year 2023 were a record 18,119 Boe/d, or 6,613,321 Boe, comprised of 4,579,942 Bbls of oil, 6,339,158 Mcf of natural gas, and 976,852 Bbls of NGLs. Full year 2022 net sales averaged 12,364 Boe/d, or 4,512,610 Boe, which included 3,459,840 Bbls of oil, 4,088,642 Mcf of natural gas, and 371,329 Bbls of NGLs. The increase in sales volumes was a direct result of a full year of production from the Stronghold Acquisition that closed in August 2022 and partial year impact from the Founders Acquisition that closed in August 2023, as well as strong organic growth from the Company’s targeted capital spending program.
For the full year 2023, the Company’s realized crude oil sales price was $76.21 per barrel, the natural gas sales price was $0.05 per Mcf, and the NGLs sales price was $11.95 per barrel. The combined average sales price for full year 2023 was $54.60 per Boe compared to $76.95 per Boe for full year 2022.
For the full year 2023, LOE was $70.2 million, or $10.61 per Boe, versus $47.7 million, or $10.57 per Boe, for full year 2022. The increase in LOE on an absolute basis was primarily associated with a 47% increase in production, as well as increased costs for goods and services due to higher activity levels.
For the full year 2023, G&A was $29.2 million, or $4.41 per Boe, compared to $27.1 million, or $6.00 per Boe for full year 2022. G&A, excluding share-based compensation, was $20.4 million, or $3.08 per Boe, compared to $19.9 million, or $4.42 per Boe for full year 2022. Excluding Transaction Costs, full year 2023 G&A, net of share-based compensation, was $3.01 per Boe — a 24% decrease from full year 2022.
2024 Capital Investment, Sales Volumes, and Operating Expense Guidance
In January, the Company commenced its 2024 development program that includes two rigs (one horizontal and one vertical) and is focused on slightly growing oil volumes while maintaining year-over-year overall production levels. The Company is utilizing a phased (versus continuous) capital drilling program in order to maximize free cash flow.
For full year 2024, Ring expects total capital spending of $135 million to $175 million that includes a balanced and capital efficient combination of drilling, completing and placing on production 18 to 24 Hz and 20 to 30 vertical wells across the Company’s asset portfolio. Additionally, the full year capital spending program includes funds for targeted well recompletions, capital workovers, infrastructure upgrades, reactivations, and leasing costs, as well as non-operated drilling, completion, and capital workovers.
All projects and estimates are based on assumed WTI oil prices of $70 to $90 per barrel and Henry Hub prices of $2.00 to $3.00 per Mcf. As in the past, Ring has designed its spending program with flexibility to respond to changes in commodity prices and other market conditions as appropriate.
Based on the $155 million mid-point of spending guidance, the Company expects the following estimated allocation of capital investment, including:
•73% for drilling, completion, and related infrastructure;
•24% for recompletions and capital workovers; and
•3% for land, environmental and emission reducing upgrades, and non-operated capital.
The Company remains focused on continuing to generate Adjusted Free Cash Flow. All 2024 planned capital expenditures will be fully funded by cash on hand and cash from operations, and excess Adjusted Free Cash Flow is currently targeted for further debt reduction.
The Company currently forecasts full year 2024 oil sales volumes of 12,600 to 13,300 Bo/d compared with full year 2023 oil sales volumes of 12,548 Bo/d, with the mid-point of guidance reflecting a 3% increase.
The guidance in the table below represents the Company's current good faith estimate of the range of likely future results for the first quarter and full year of 2024. Guidance could be affected by the factors discussed below in the "Safe Harbor Statement" section.
| | | | | | | | | | | | | | |
| | Q1 | | FY |
| | 2024 | | 2024 |
| | | | |
| Sales Volumes: | | | | |
Total Oil (Bo/d) | | 12,420-12,765 | | 12,600-13,300 |
Mid Point for Oil (Bo/d) | | 12,593 | | 12,950 |
| Total (Boe/d) | | 18,000-18,500 | | 18,000-19,000 |
| Oil (%) | | 69% | | 70% |
| NGLs (%) | | 15% | | 15% |
| Gas (%) | | 16% | | 15% |
| | | | |
| Capital Program: | | | | |
Capital spending(1) (millions) | | $37-$42 | | $135-$175 |
Mid Point (millions) | | $39.5 | | $155 |
Hz wells drilled | | 4-5 | | 18-24 |
Vertical wells drilled | | 4-6 | | 20-30 |
Wells completed and online | | 8-11 | | 38-54 |
| | | | |
| Operating Expenses: | | | | |
| LOE (per Boe) | | $10.75-$11.25 | | $10.50-$11.50 |
(1) In addition to Company-directed drilling and completion activities, the capital spending outlook includes funds for targeted well recompletions, capital workovers, infrastructure upgrades and well reactivations. Also included is anticipated spending for leasing costs, and non-operated drilling, completion, and capital workovers.
Year-End 2023 Proved Reserves
The Company's year-end 2023 SEC proved reserves were 129.8 MMBoe compared to 138.1 MMBoe at year-end 2022. During 2023, Ring recorded reserve additions of 8.2 MMBoe for acquisitions and 4.8 MMBoe for extensions, discoveries and improved recovery. Offsetting these additions were 5.7 MMBoe related to the sale of non-core assets, 6.6 MMBoe of production, 5.3 MMBoe for reductions in year-over-year pricing, and 3.7 MMBoe related to changes in performance and other economic factors.
The SEC twelve-month first day of the month average prices used for year-end 2023 were $74.70 per barrel of crude oil and $2.637 per MMBtu of natural gas, both before adjustment for quality, transportation, fees, energy content, and regional price differentials, while for year-end 2022 they were $90.15 per barrel of crude oil and $6.358 per MMBtu of natural gas.
Year-end 2023 SEC proved reserves were comprised of approximately 63% crude oil, 19% natural gas, and 18% natural gas liquids. At year end, approximately 68% of 2023 proved reserves were classified as proved developed and 32% as proved undeveloped. This is
compared to year-end 2022 when approximately 65% of proved reserves were classified as proved developed and 35% were classified as proved undeveloped.
The PV-10 value at year-end 2023 was $1,647.0 million versus $2,773.7 million at the end of 2022.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Oil (Bbl) | | Gas (Mcf) | | Natural Gas Liquids (Bbl) | | Net
(Boe) | | PV-10(1) |
| | | | | | | | | | |
| Balance, December 31, 2022 | | 88,704,743 | | | 157,870,449 | | | 23,105,658 | | | 138,122,143 | | | $ | 2,773,656,500 | |
| | | | | | | | | | |
| Purchase of minerals in place | | 6,543,640 | | | 3,372,965 | | | 1,089,382 | | | 8,195,183 | | | |
| Extensions, discoveries and improved recovery | | 3,098,845 | | | 4,113,480 | | | 1,014,343 | | | 4,798,768 | | | |
| Sales of minerals in place | | (4,897,921) | | | (2,674,955) | | | (392,953) | | | (5,736,700) | | | |
| Production | | (4,579,942) | | | (6,339,158) | | | (976,852) | | | (6,613,320) | | | |
| Revisions of previous quantity estimates | | (6,728,088) | | | (9,946,459) | | | (621,014) | | | (9,006,845) | | | |
| | | | | | | | | | |
| Balance, December 31, 2023 | | 82,141,277 | | | 146,396,322 | | | 23,218,564 | | | 129,759,229 | | | $ | 1,647,031,127 | |
(1) PV-10 includes provision for plug and abandonment (“P&A”) less salvage, and excludes the full provision for asset retirement obligations or any provision for income taxes. This is a non-GAAP financial measure as defined by the SEC and is derived from the Standardized Measure of Discounted Futures Net Cash Flows, which is the most directly comparable generally accepted accounting principles (“GAAP”) measure.
In accordance with guidelines established by the SEC, estimated proved reserves as of December 31, 2023 were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average commodity price for each product, calculated as the unweighted arithmetic average of the first-day-of-the-month price for the year ended December 31, 2023. The SEC average prices used for year-end 2023 were $74.70 per barrel of crude oil (WTI) and $2.637 per MMBtu of natural gas (Henry Hub), both before adjustment for quality, transportation, fees, energy content, and regional price differentials. Such prices were held constant throughout the estimated lives of the reserves. Future production and development costs are based on year-end costs with no escalations.
Standardized Measure of Discounted Future Net Cash Flows
Ring’s standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves and changes in the standardized measure as described below were prepared in accordance with GAAP.
| | | | | | | | | | | | | | |
| As of December 31, | | 2023 | | 2022 |
| | | | |
| Future cash inflows | | $ | 6,622,410,752 | | | $ | 9,871,961,000 | |
| Future production costs | | (2,413,303,488) | | | (2,751,896,250) | |
Future development costs (1) | | (562,063,424) | | | (647,196,750) | |
| Future income taxes | | (548,664,988) | | | (1,142,147,641) | |
| Future net cash flows | | 3,098,378,852 | | | 5,330,720,359 | |
| 10% annual discount for estimated timing of cash flows | | (1,699,193,661) | | | (3,058,606,841) | |
| | | | |
| Standardized Measure of Discounted Future Net Cash Flows | | $ | 1,399,185,191 | | | $ | 2,272,113,518 | |
(1) Future development costs include not only development costs but also future asset retirement costs.
Reconciliation of PV-10 to Standardized Measure
PV-10 is derived from the Standardized Measure of Discounted Future Net Cash Flows (“Standardized Measure”), which is the most directly comparable GAAP financial measure for proved reserves calculated using SEC pricing. PV-10 is a computation of the Standardized Measure on a pre-tax basis. PV-10 is equal to the Standardized Measure at the applicable date, before deducting future income taxes, discounted at 10 percent. We believe that the presentation of PV-10 is relevant and useful to investors because it presents the discounted future net cash flows attributable to our estimated net proved reserves prior to taking into account future corporate income taxes, and it is a useful measure for evaluating the relative monetary significance of our oil and natural gas properties. Further, investors may utilize the measure as a basis for comparison of the relative size and value of our reserves to other companies without regard to the specific tax characteristics of such entities. Moreover, GAAP does not provide a measure of estimated future net cash flows for reserves other than proved reserves or for reserves calculated using prices other than SEC prices. We use this measure when assessing the potential return on investment related to our oil and natural gas properties. PV-10, however, is not a substitute for the Standardized Measure. Our PV-10 measure and the Standardized Measure do not purport to represent the fair value of our oil and natural gas reserves.
The following table reconciles the PV-10 value of the Company’s estimated proved reserves as of December 31, 2023 to the Standardized Measure:
| | | | | | | | | | | |
SEC Pricing Proved Reserves |
Standardized Measure Reconciliation | | |
Present Value of Estimated Future Net Revenues (PV-10) | | $ | 1,647,031,127 | |
Future Income Taxes, Discounted at 10% | | 247,845,936 | |
Standardized Measure of Discounted Future Net Cash Flows | | $ | 1,399,185,191 | |
Conference Call Information
Ring will hold a conference call on Friday, March 8, 2024 at 11:00 a.m. ET to discuss its fourth quarter and full year 2023 operational and financial results. An updated investor presentation will be posted to the Company’s website prior to the conference call.
To participate in the conference call, interested parties should dial 833-953-2433 at least five minutes before the call is to begin. Please reference the “Ring Energy Fourth Quarter and Full Year 2023 Earnings Conference Call”. International callers may participate by dialing 412-317-5762. The call will also be webcast and available on Ring’s website at www.ringenergy.com under “Investors” on the “News & Events” page. An audio replay will also be available on the Company’s website following the call.
About Ring Energy, Inc.
Ring Energy, Inc. is an oil and gas exploration, development, and production company with current operations focused on the development of its Permian Basin assets. For additional information, please visit www.ringenergy.com.
Safe Harbor Statement
This release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical fact included in this release, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this release, the words “could,” “may,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “guidance,” “project,” “goal,” “plan,” “target” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on management’s current expectations and assumptions about future events and are based on currently available information as to the outcome and
timing of future events. However, whether actual results and developments will conform to expectations is subject to a number of material risks and uncertainties, including but not limited to: declines in oil, natural gas liquids or natural gas prices; the level of success in exploration, development and production activities; adverse weather conditions that may negatively impact development or production activities; the timing of exploration and development expenditures; inaccuracies of reserve estimates or assumptions underlying them; revisions to reserve estimates as a result of changes in commodity prices; impacts to financial statements as a result of impairment write-downs; risks related to level of indebtedness and periodic redeterminations of the borrowing base and interest rates under the Company’s credit facility; Ring’s ability to generate sufficient cash flows from operations to meet the internally funded portion of its capital expenditures budget; the impacts of hedging on results of operations; and Ring’s ability to replace oil and natural gas reserves. Such statements are subject to certain risks and uncertainties which are disclosed in the Company’s reports filed with the SEC, including its Form 10-K for the fiscal year ended December 31, 2023, and its other filings with the SEC. Readers and investors are cautioned that the Company’s actual results may differ materially from those described in the forward-looking statements due to a number of factors, including, but not limited to, the Company’s ability to acquire productive oil and/or gas properties or to successfully drill and complete oil and/or gas wells on such properties, general economic conditions both domestically and abroad, and the conduct of business by the Company, and other factors that may be more fully described in additional documents set forth by the Company. Should one or more of the risks or uncertainties described in this release occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements, expressed or implied, included in this release are expressly qualified in their entirety by this safe harbor statement. This safe harbor statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Ring undertakes no obligation to revise or update publicly any forward-looking statements except as required by law.
Contact Information
Al Petrie Advisors
Al Petrie, Senior Partner
Phone: 281-975-2146
Email: apetrie@ringenergy.com
RING ENERGY, INC.
Condensed Statements of Operations
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited) | | | | |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
| Oil, Natural Gas, and Natural Gas Liquids Revenues | $ | 99,942,718 | | | $ | 93,681,798 | | | $ | 99,697,682 | | | $ | 361,056,001 | | | $ | 347,249,537 | |
| | | | | | | | | |
| Costs and Operating Expenses | | | | | | | | | |
| Lease operating expenses | 18,732,082 | | | 18,015,348 | | | 17,411,645 | | | 70,158,227 | | | 47,695,351 | |
| Gathering, transportation and processing costs | 464,558 | | | (4,530) | | | (16,223) | | | 457,573 | | | 1,830,024 | |
| Ad valorem taxes | 1,637,722 | | | 1,779,163 | | | 1,570,039 | | | 6,757,841 | | | 4,670,617 | |
| Oil and natural gas production taxes | 4,961,768 | | | 4,753,289 | | | 5,186,644 | | | 18,135,336 | | | 17,125,982 | |
| Depreciation, depletion and amortization | 24,556,654 | | | 21,989,034 | | | 20,885,774 | | | 88,610,291 | | | 55,740,767 | |
| | | | | | | | | |
| Asset retirement obligation accretion | 351,786 | | | 354,175 | | | 365,747 | | | 1,425,686 | | | 983,432 | |
| Operating lease expense | 175,090 | | | 138,220 | | | 113,138 | | | 541,801 | | | 363,908 | |
| General and administrative expense (including share-based compensation) | 8,164,799 | | | 7,083,574 | | | 8,346,896 | | | 29,188,755 | | | 27,095,323 | |
| | | | | | | | | |
| Total Costs and Operating Expenses | 59,044,459 | | | 54,108,273 | | | 53,863,660 | | | 215,275,510 | | | 155,505,404 | |
| | | | | | | | | |
| Income (Loss) from Operations | 40,898,259 | | | 39,573,525 | | | 45,834,022 | | | 145,780,491 | | | 191,744,133 | |
| | | | | | | | | |
| Other Income (Expense) | | | | | | | | | |
| Interest income | 96,984 | | | 80,426 | | | — | | | 257,155 | | | 4 | |
| Interest (expense) | (11,603,892) | | | (11,381,754) | | | (9,468,684) | | | (43,926,732) | | | (23,167,729) | |
| Gain (loss) on derivative contracts | 29,250,352 | | | (39,222,755) | | | (19,330,689) | | | 2,767,162 | | | (21,532,659) | |
| Gain (loss) on disposal of assets | 44,981 | | | — | | | — | | | (87,128) | | | — | |
| Other income | 72,725 | | | — | | | — | | | 198,935 | | | — | |
| Net Other Income (Expense) | 17,861,150 | | | (50,524,083) | | | (28,799,373) | | | (40,790,608) | | | (44,700,384) | |
| | | | | | | | | |
| Income (Loss) Before Provision for Income Taxes | 58,759,409 | | | (10,950,558) | | | 17,034,649 | | | 104,989,883 | | | 147,043,749 | |
| | | | | | | | | |
| Benefit from (Provision for) Income Taxes | (7,862,930) | | | 3,411,336 | | | (2,541,980) | | | (125,242) | | | (8,408,724) | |
| | | | | | | | | |
| Net Income (Loss) | $ | 50,896,479 | | | $ | (7,539,222) | | | $ | 14,492,669 | | | $ | 104,864,641 | | | $ | 138,635,025 | |
| | | | | | | | | |
| Basic Earnings (Loss) per share | $ | 0.26 | | | $ | (0.04) | | | $ | 0.09 | | | $ | 0.55 | | | $ | 1.14 | |
| Diluted Earnings (Loss) per share | $ | 0.26 | | | $ | (0.04) | | | $ | 0.08 | | | $ | 0.54 | | | $ | 0.98 | |
| | | | | | | | | |
| Basic Weighted-Average Shares Outstanding | 195,687,725 | | 195,361,476 | | 162,743,445 | | 190,589,143 | | 121,264,175 |
| Diluted Weighted-Average Shares Outstanding | 197,848,812 | | 195,361,476 | | 178,736,799 | | 195,364,850 | | 141,754,668 |
RING ENERGY, INC.
Condensed Operating Data
(Unaudited)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
| Net sales volumes: | | | | | | | | | |
| Oil (Bbls) | 1,254,619 | | 1,106,531 | | 1,121,371 | | 4,579,942 | | 3,459,840 |
Natural gas (Mcf)(1) | 1,613,102 | | 1,567,104 | | 1,680,401 | | 6,339,158 | | 4,088,642 |
Natural gas liquids (Bbls)(1) | 261,020 | | 243,142 | | 241,277 | | 976,852 | | 371,329 |
Total oil, natural gas and natural gas liquids (Boe)(2) | 1,784,490 | | 1,610,857 | | 1,642,715 | | 6,613,321 | | 4,512,610 |
| | | | | | | | | |
| % Oil | 70 | % | | 69 | % | | 68 | % | | 69 | % | | 77 | % |
% Natural gas | 15 | % | | 16 | % | | 17 | % | | 16 | % | | 15 | % |
% Natural gas liquids | 15 | % | | 15 | % | | 15 | % | | 15 | % | | 8 | % |
| | | | | | | | | |
Average daily sales volumes: | | | | | | | | | |
Oil (Bbls/d) | 13,637 | | 12,028 | | 12,189 | | 12,548 | | 9,479 |
Natural gas (Mcf/d)(1) | 17,534 | | 17,034 | | 18,265 | | 17,368 | | 11,202 |
Natural gas liquids (Bbls/d)(1) | 2,837 | | 2,643 | | 2,623 | | 2,676 | | 1,017 |
| Average daily equivalent sales (Boe/d) | 19,397 | | 17,509 | | 17,856 | | 18,119 | | 12,364 |
| | | | | | | | | |
| Average realized sales prices: | | | | | | | | | |
| Oil ($/Bbl) | 77.33 | | 81.69 | | 81.62 | | 76.21 | | 92.80 |
Natural gas ($/Mcf)(1) | -0.12 | | 0.36 | | 2.39 | | 0.05 | | 4.57 |
Natural gas liquids ($/Bbls)(1) | 11.92 | | 11.22 | | 17.21 | | 11.95 | | 20.18 |
| Barrel of oil equivalent ($/Boe) | 56.01 | | 58.16 | | 60.69 | | 54.60 | | 76.95 |
| | | | | | | | | |
| Average costs and expenses per Boe ($/Boe): | | | | | | | | | |
| Lease operating expenses | 10.50 | | 11.18 | | 10.60 | | 10.61 | | 10.57 |
| Gathering, transportation and processing costs | 0.26 | | 0.00 | | -0.01 | | 0.07 | | 0.41 |
| Ad valorem taxes | 0.92 | | 1.10 | | 0.96 | | 1.02 | | 1.04 |
| Oil and natural gas production taxes | 2.78 | | 2.95 | | 3.16 | | 2.74 | | 3.80 |
| Depreciation, depletion and amortization | 13.76 | | 13.65 | | 12.71 | | 13.40 | | 12.35 |
| | | | | | | | | |
| Asset retirement obligation accretion | 0.20 | | 0.22 | | 0.22 | | 0.22 | | 0.22 |
| Operating lease expense | 0.10 | | 0.09 | | 0.07 | | 0.08 | | 0.08 |
G&A (including share-based compensation) | 4.58 | | 4.40 | | 5.08 | | 4.41 | | 6.00 |
G&A (excluding share-based compensation) | 3.20 | | 3.05 | | 3.74 | | 3.08 | | 4.42 |
G&A (excluding share-based compensation and transaction costs) | 3.00 | | 3.15 | | 3.14 | | 3.01 | | 3.94 |
(1) Beginning July 1, 2022, revenues were reported on a three-stream basis, separately reporting crude oil, natural gas, and natural gas liquids volumes and sales. For periods prior to July 1, 2022, volumes and sales for natural gas liquids were presented with natural gas.
(2) Boe is determined using the ratio of six Mcf of natural gas to one Bbl of oil (totals may not compute due to rounding.) The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, natural gas, and natural gas liquids may differ significantly.
RING ENERGY, INC.
Condensed Balance Sheets
| | | | | | | | | | | | | | |
| As of December 31, | | 2023 | | 2022 |
| ASSETS | | | | |
| Current Assets | | | | |
| Cash and cash equivalents | | $ | 296,384 | | | $ | 3,712,526 | |
| Accounts receivable | | 38,965,002 | | | 42,448,719 | |
Joint interest billing receivables, net | | 2,422,274 | | | 983,802 | |
| Derivative assets | | 6,215,374 | | | 4,669,162 | |
| Inventory | | 6,136,935 | | | 9,250,717 | |
| Prepaid expenses and other assets | | 1,874,850 | | | 2,101,538 | |
| Total Current Assets | | 55,910,819 | | | 63,166,464 | |
| Properties and Equipment | | | | |
| Oil and natural gas properties, full cost method | | 1,663,548,249 | | | 1,463,838,595 | |
| Financing lease asset subject to depreciation | | 3,896,316 | | | 3,019,476 | |
| Fixed assets subject to depreciation | | 3,228,793 | | | 3,147,125 | |
| Total Properties and Equipment | | 1,670,673,358 | | | 1,470,005,196 | |
| Accumulated depreciation, depletion and amortization | | (377,252,572) | | | (289,935,259) | |
| Net Properties and Equipment | | 1,293,420,786 | | | 1,180,069,937 | |
| Operating lease asset | | 2,499,592 | | | 1,735,013 | |
| Derivative assets | | 11,634,714 | | | 6,129,410 | |
| Deferred financing costs | | 13,030,481 | | | 17,898,973 | |
| Total Assets | | $ | 1,376,496,392 | | | $ | 1,268,999,797 | |
| | | | |
| LIABILITIES AND STOCKHOLDERS’ EQUITY | | | | |
| Current Liabilities | | | | |
| Accounts payable | | $ | 104,064,124 | | | $ | 111,398,268 | |
| | | | |
| Financing lease liability | | 956,254 | | | 709,653 | |
| Operating lease liability | | 568,176 | | | 398,362 | |
| Derivative liabilities | | 7,520,336 | | | 13,345,619 | |
| Notes payable | | 533,734 | | | 499,880 | |
| Deferred cash payment | | — | | | 14,807,276 | |
| Asset retirement obligations | | 165,642 | | | 635,843 | |
| Total Current Liabilities | | 113,808,266 | | | 141,794,901 | |
| | | | |
| Non-current Liabilities | | | | |
| Deferred income taxes | | 8,552,045 | | | 8,499,016 | |
| Revolving line of credit | | 425,000,000 | | | 415,000,000 | |
| Financing lease liability, less current portion | | 906,330 | | | 1,052,479 | |
| Operating lease liability, less current portion | | 2,054,041 | | | 1,473,897 | |
| Derivative liabilities | | 11,510,368 | | | 10,485,650 | |
| Asset retirement obligations | | 28,082,442 | | | 29,590,463 | |
| Total Liabilities | | 589,913,492 | | | 607,896,406 | |
| Commitments and contingencies | | | | |
| Stockholders' Equity | | | | |
| Preferred stock - $0.001 par value; 50,000,000 shares authorized; no shares issued or outstanding | | — | | | — | |
Common stock - $0.001 par value; 450,000,000 shares authorized; 196,837,001 shares and 175,530,212 shares issued and outstanding, respectively | | 196,837 | | | 175,530 | |
| Additional paid-in capital | | 795,834,675 | | | 775,241,114 | |
| Accumulated deficit | | (9,448,612) | | | (114,313,253) | |
| Total Stockholders’ Equity | | 786,582,900 | | | 661,103,391 | |
| Total Liabilities and Stockholders' Equity | | $ | 1,376,496,392 | | | $ | 1,268,999,797 | |
RING ENERGY, INC.
Condensed Statements of Cash Flows
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | (Unaudited) | | | | |
| | Three Months Ended | | Twelve Months Ended |
| | December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| | 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | | |
| Cash Flows From Operating Activities | | | | | | | | | | |
| Net income (loss) | | $ | 50,896,479 | | | $ | (7,539,222) | | | $ | 14,492,669 | | | $ | 104,864,641 | | | $ | 138,635,025 | |
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | | | | | | | | | |
| Depreciation, depletion and amortization | | 24,556,654 | | | 21,989,034 | | | 20,885,774 | | | 88,610,291 | | | 55,740,767 | |
| Asset retirement obligation accretion | | 351,786 | | | 354,175 | | | 365,747 | | | 1,425,686 | | | 983,432 | |
| Amortization of deferred financing costs | | 1,221,479 | | | 1,258,466 | | | 1,222,400 | | | 4,920,714 | | | 2,706,021 | |
| Share-based compensation | | 2,458,682 | | | 2,170,735 | | | 2,198,043 | | | 8,833,425 | | | 7,162,231 | |
| Bad debt expense | | 92,142 | | | 19,656 | | | 242,247 | | | 134,007 | | | 242,247 | |
| Deferred income tax expense (benefit) | | 7,735,437 | | | (3,585,002) | | | 2,890,984 | | | (425,275) | | | 8,720,992 | |
| Excess tax expense (benefit) related to share-based compensation | | 319,541 | | | 7,886 | | | (312,268) | | | 478,304 | | | (312,268) | |
| (Gain) loss on derivative contracts | | (29,250,352) | | | 39,222,755 | | | 19,330,689 | | | (2,767,162) | | | 21,532,659 | |
| Cash received (paid) for derivative settlements, net | | (3,255,192) | | | (5,350,798) | | | (13,932,072) | | | (9,084,920) | | | (62,525,954) | |
Changes in operating assets and liabilities: | | | | | | | | | | |
| Accounts receivable | | 6,825,601 | | | (14,419,854) | | | 4,086,757 | | | 1,154,085 | | | (17,214,150) | |
| Inventory | | (588,100) | | | 1,778,460 | | | (5,597,845) | | | 3,113,782 | | | (5,597,845) | |
| Prepaid expenses and other assets | | 158,163 | | | 1,028,203 | | | 1,145,031 | | | 226,688 | | | (1,163,509) | |
| Accounts payable | | (4,952,335) | | | 18,562,202 | | | 16,816,386 | | | (1,451,422) | | | 50,808,461 | |
| Settlement of asset retirement obligation | | (836,778) | | | (105,721) | | | (193,036) | | | (1,862,385) | | | (2,741,380) | |
| Net Cash Provided by Operating Activities | | 55,733,207 | | | 55,390,975 | | | 63,641,506 | | | 198,170,459 | | | 196,976,729 | |
| | | | | | | | | | |
| Cash Flows From Investing Activities | | | | | | | | | | |
| Payments for the Stronghold Acquisition | | — | | | — | | | 5,535,839 | | | (18,511,170) | | | (177,823,787) | |
| Payments for the Founders Acquisition | | (12,324,388) | | | (49,902,757) | | | — | | | (62,227,145) | | | — | |
| Payments to purchase oil and natural gas properties | | (557,323) | | | (726,519) | | | (352,012) | | | (2,162,585) | | | (1,563,703) | |
| Payments to develop oil and natural gas properties | | (39,563,282) | | | (40,444,810) | | | (45,556,105) | | | (152,559,314) | | | (129,332,155) | |
| Payments to acquire or improve fixed assets subject to depreciation | | (282,519) | | | (183,904) | | | (161,347) | | | (492,317) | | | (319,945) | |
| Sale of fixed assets subject to depreciation | | (1) | | | — | | | — | | | 332,229 | | | 134,600 | |
| Proceeds from divestiture of oil and natural gas properties | | 1,500,000 | | | — | | | (1,366) | | | 1,554,558 | | | 23,700 | |
| Proceeds from sale of Delaware properties | | (7,993) | | | (384,225) | | | — | | | 7,600,699 | | | — | |
| Proceeds from sale of New Mexico properties | | (420,745) | | | 4,312,502 | | | — | | | 3,891,757 | | | — | |
Net Cash Used in Investing Activities | | (51,656,251) | | | (87,329,713) | | | (40,534,991) | | | (222,573,288) | | | (308,881,290) | |
| | | | | | | | | | |
| Cash Flows From Financing Activities | | | | | | | | | | |
| Proceeds from revolving line of credit | | 46,000,000 | | | 94,500,000 | | | 44,000,000 | | | 225,000,000 | | | 636,000,000 | |
| Payments on revolving line of credit | | (49,000,000) | | | (63,500,000) | | | (64,000,000) | | | (215,000,000) | | | (511,000,000) | |
Proceeds from issuance of common stock from warrant exercises | | — | | | — | | | 640,000 | | | 12,301,596 | | | 8,203,126 | |
| | | | | | | | | | |
Payments for taxes withheld on vested restricted shares, net | | (225,788) | | | (18,302) | | | (256,715) | | | (520,153) | | | (521,199) | |
| Proceeds from notes payable | | 72,442 | | | — | | | 78,051 | | | 1,637,513 | | | 1,323,354 | |
| Payments on notes payable | | (488,776) | | | (462,606) | | | (455,802) | | | (1,603,659) | | | (1,409,884) | |
| Payment of deferred financing costs | | (52,222) | | | — | | | (129,026) | | | (52,222) | | | (18,891,528) | |
| Reduction of financing lease liabilities | | (224,809) | | | (191,748) | | | (161,064) | | | (776,388) | | | (495,098) | |
Net Cash Provided by (Used in) Financing Activities | | (3,919,153) | | | 30,327,344 | | | (20,284,556) | | | 20,986,687 | | | 113,208,771 | |
| | | | | | | | | | |
| Net Increase (Decrease) in Cash | | 157,803 | | | (1,611,394) | | | 2,821,959 | | | (3,416,142) | | | 1,304,210 | |
| Cash at Beginning of Period | | 138,581 | | | 1,749,975 | | | 890,567 | | | 3,712,526 | | | 2,408,316 | |
| Cash at End of Period | | $ | 296,384 | | | $ | 138,581 | | | $ | 3,712,526 | | | $ | 296,384 | | | $ | 3,712,526 | |
RING ENERGY, INC.
Financial Commodity Derivative Positions
As of December 31, 2023
The following table reflects the prices of contracts outstanding as of December 31, 2023 (Quantities are in barrels of the oil derivative contracts and in million British thermal units (MMBtu) for the natural gas derivative contracts):
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Oil Hedges (WTI) |
| Q1 2024 | | Q2 2024 | | Q3 2024 | | Q4 2024 | | Q1 2025 | | Q2 2025 | | Q3 2025 | | Q4 2025 |
| | | | | | | | | | | | | | | |
| Swaps: | | | | | | | | | | | | | | | |
| Hedged volume (Bbl) | 170,625 | | | 156,975 | | | 282,900 | | | 368,000 | | | — | | | — | | | 184,000 | | | — | |
| Weighted average swap price | $ | 67.40 | | | $ | 66.40 | | | $ | 65.49 | | | $ | 68.43 | | | $ | — | | | $ | — | | | $ | 73.35 | | | $ | — | |
| | | | | | | | | | | | | | | |
| Deferred premium puts: | | | | | | | | | | | | | | | |
| Hedged volume (Bbl) | 45,500 | | | 45,500 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Weighted average strike price | $ | 84.70 | | | $ | 82.80 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
| Weighted average deferred premium price | $ | 17.15 | | | $ | 17.49 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
| | | | | | | | | | | | | | | |
| Two-way collars: | | | | | | | | | | | | | | | |
| Hedged volume (Bbl) | 371,453 | | | 334,947 | | | 230,000 | | | 128,800 | | | 474,750 | | | 464,100 | | | 225,400 | | | 404,800 | |
| Weighted average put price | $ | 64.27 | | | $ | 64.32 | | | $ | 64.00 | | | $ | 60.00 | | | $ | 57.06 | | | $ | 60.00 | | | $ | 65.00 | | | $ | 60.00 | |
| Weighted average call price | $ | 79.92 | | | $ | 79.16 | | | $ | 76.50 | | | $ | 73.24 | | | $ | 75.82 | | | $ | 69.85 | | | $ | 78.91 | | | $ | 75.68 | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Gas Hedges (Henry Hub) |
| Q1 2024 | | Q2 2024 | | Q3 2024 | | Q4 2024 | | Q1 2025 | | Q2 2025 | | Q3 2025 | | Q4 2025 |
| | | | | | | | | | | | | | | |
| NYMEX Swaps: | | | | | | | | | | | | | | | |
| Hedged volume (MMBtu) | 101,615 | | | 138,053 | | | 121,587 | | | 644,946 | | | 616,199 | | | 591,725 | | | 285,200 | | | — | |
| Weighted average swap price | $ | 3.62 | | | $ | 3.61 | | | $ | 3.59 | | | $ | 4.45 | | | $ | 3.78 | | | $ | 3.43 | | | $ | 3.73 | | | $ | — | |
| | | | | | | | | | | | | | | |
Two-way collars: | | | | | | | | | | | | | | | |
| Hedged volume (MMBtu) | 417,000 | | | 605,150 | | | 584,200 | | | 27,600 | | | 27,000 | | | 27,300 | | | 308,200 | | | 598,000 | |
| Weighted average put price | $ | 3.94 | | | $ | 3.94 | | | $ | 3.94 | | | $ | 3.00 | | | $ | 3.00 | | | $ | 3.00 | | | $ | 3.00 | | | $ | 3.00 | |
| | | | | | | | | | | | | | | |
| Weighted average call price | $ | 6.15 | | | $ | 6.16 | | | $ | 6.17 | | | $ | 4.15 | | | $ | 4.15 | | | $ | 4.15 | | | $ | 4.75 | | | $ | 4.15 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Oil Hedges (basis differential) |
| Q1 2024 | | Q2 2024 | | Q3 2024 | | Q4 2024 | | Q1 2025 | | Q2 2025 | | Q3 2025 | | Q4 2025 |
| | | | | | | | | | | | | | | |
Argus basis swaps: | | | | | | | | | | | | | | | |
Hedged volume (Bbl) | 240,000 | | | 364,000 | | | 368,000 | | | 368,000 | | | 270,000 | | | 273,000 | | | 276,000 | | | 276,000 | |
Weighted average spread price (1) | $ | 1.15 | | | $ | 1.15 | | | $ | 1.15 | | | $ | 1.15 | | | $ | 1.00 | | | $ | 1.00 | | | $ | 1.00 | | | $ | 1.00 | |
(1) The oil basis swap hedges are calculated as the fixed price (weighted average spread price above) less the difference between WTI Midland and WTI Cushing, in the issue of Argus Americas Crude.
RING ENERGY, INC.
Non-GAAP Information
Certain financial information included in this release are not measures of financial performance recognized by accounting principles generally accepted in the United States (“GAAP”). These non-GAAP financial measures are “Adjusted Net Income”, “Adjusted EBITDA”, “Adjusted Free Cash Flow” or “AFCF,” “Adjusted Cash Flow from Operations” or “ACFFO,” “G&A Excluding Share-Based Compensation,” “G&A Excluding Share-Based Compensation and Transaction Costs,” “Leverage Ratio,” “Current Ratio,” “Cash Return on Capital Employed” or “CROCE,” and “All-In Cash Operating Costs.” Management uses these non-GAAP financial measures in its analysis of performance. In addition, Adjusted EBITDA is a key metric used to determine certain of the Company’s incentive compensation awards. These disclosures may not be viewed as a substitute for results determined in accordance with GAAP and are not necessarily comparable to non-GAAP performance measures which may be reported by other companies.
Reconciliation of Net Income (Loss) to Adjusted Net Income
“Adjusted Net Income” is calculated as net income (loss) minus the estimated after-tax impact of share-based compensation, ceiling test impairment, unrealized gains and losses on changes in the fair value of derivatives, and related transaction costs. Adjusted Net Income is presented because the timing and amount of these items cannot be reasonably estimated and affect the comparability of operating results from period to period, and current period to prior periods. The Company believes that the presentation of Adjusted Net Income provides useful information to investors as it is one of the metrics management uses to assess the Company’s ongoing operating and financial performance, and also is a useful metric for investors to compare our results with our peers.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited for All Periods) | | |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| Total | | Per share - diluted | | Total | | Per share - diluted | | Total | | Per share - diluted | | Total | | Per share - diluted | | Total | | Per share - diluted |
| Net Income (Loss) | $ | 50,896,479 | | | $ | 0.26 | | | $ | (7,539,222) | | | $ | (0.04) | | | $ | 14,492,669 | | | $ | 0.08 | | | $ | 104,864,641 | | | $ | 0.54 | | | $ | 138,635,025 | | | $ | 0.98 | |
| | | | | | | | | | | | | | | | | | | |
| Share-based compensation | 2,458,682 | | | 0.01 | | | 2,170,735 | | | 0.01 | | | 2,198,043 | | | 0.01 | | | 8,833,425 | | | 0.05 | | | 7,162,231 | | | 0.05 | |
| | | | | | | | | | | | | | | | | | | |
| Unrealized loss (gain) on change in fair value of derivatives | (32,505,544) | | | (0.16) | | | 33,871,957 | | | 0.17 | | | 5,398,617 | | | 0.03 | | | (11,852,082) | | | (0.07) | | | (40,993,295) | | | (0.29) | |
Transaction costs - executed A&D | 354,616 | | | — | | | (157,641) | | | — | | | 993,027 | | | 0.01 | | | 417,166 | | | — | | | 2,135,990 | | | 0.02 | |
| Tax impact on adjusted items | (35,631) | | | — | | | (2,059,802) | | | (0.01) | | | (1,281,788) | | | (0.01) | | | (1,788,248) | | | (0.01) | | | 536,088 | | | — | |
| | | | | | | | | | | | | | | | | | | |
| Adjusted Net Income | $ | 21,168,602 | | | $ | 0.11 | | | $ | 26,286,027 | | | $ | 0.13 | | | $ | 21,800,568 | | | $ | 0.12 | | | $ | 100,474,902 | | | $ | 0.51 | | | $ | 107,476,039 | | | $ | 0.76 | |
| | | | | | | | | | | | | | | | | | | |
Diluted Weighted-Average Shares Outstanding | 197,848,812 | | | | | 195,361,476 | | | | | 178,736,799 | | | | | 195,364,850 | | | | | 141,754,668 | | | |
| | | | | | | | | | | | | | | | | | | |
Adjusted Net Income per Diluted Share | $ | 0.11 | | | | | $ | 0.13 | | | | | $ | 0.12 | | | | | $ | 0.51 | | | | | $ | 0.76 | | | |
Reconciliation of Net Income (Loss) to Adjusted EBITDA
The Company defines “Adjusted EBITDA” as net income (loss) plus net interest expense, unrealized loss (gain) on change in fair value of derivatives, ceiling test impairment, income tax (benefit) expense, depreciation, depletion and amortization, asset retirement obligation accretion, transaction costs for executed acquisitions and divestitures (A&D), share-based compensation, loss (gain) on disposal of assets, and backing out the effect of other income. Company management believes Adjusted EBITDA is relevant and useful because it helps investors understand Ring’s operating performance and makes it easier to compare its results with those of other companies that have different financing, capital and tax structures. Adjusted EBITDA should not be considered in isolation from or as a substitute for net income, as an indication of operating performance or cash flows from operating activities or as a measure of liquidity. Adjusted EBITDA, as Ring calculates it, may not be comparable to Adjusted EBITDA measures reported by other companies. In addition, Adjusted EBITDA does not represent funds available for discretionary use.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited for All Periods) |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
| Net Income (Loss) | $ | 50,896,479 | | | $ | (7,539,222) | | | $ | 14,492,669 | | | $ | 104,864,641 | | | $ | 138,635,025 | |
| | | | | | | | | |
| Interest expense, net | 11,506,908 | | | 11,301,328 | | | 9,468,684 | | | 43,669,577 | | | 23,167,729 | |
| Unrealized loss (gain) on change in fair value of derivatives | (32,505,544) | | | 33,871,957 | | | 5,398,617 | | | (11,852,082) | | | (40,993,295) | |
| | | | | | | | | |
| Income tax (benefit) expense | 7,862,930 | | | (3,411,336) | | | 2,541,980 | | | 125,242 | | | 8,408,724 | |
| Depreciation, depletion and amortization | 24,556,654 | | | 21,989,034 | | | 20,885,774 | | | 88,610,291 | | | 55,740,767 | |
| Asset retirement obligation accretion | 351,786 | | | 354,175 | | | 365,747 | | | 1,425,686 | | | 983,432 | |
Transaction costs - executed A&D | 354,616 | | | (157,641) | | | 993,027 | | | 417,166 | | | 2,135,990 | |
| Share-based compensation | 2,458,682 | | | 2,170,735 | | | 2,198,043 | | | 8,833,425 | | | 7,162,231 | |
Loss (gain) on disposal of assets | (44,981) | | | — | | | — | | | 87,128 | | | — | |
Other income | (72,725) | | | — | | | — | | | (198,935) | | | — | |
| | | | | | | | | |
| Adjusted EBITDA | $ | 65,364,805 | | | $ | 58,579,030 | | | $ | 56,344,541 | | | $ | 235,982,139 | | | $ | 195,240,603 | |
| | | | | | | | | |
| Adjusted EBITDA Margin | 65 | % | | 63 | % | | 57 | % | | 65 | % | | 56 | % |
Reconciliations of Net Cash Provided by Operating Activities to Adjusted Free Cash Flow and Adjusted EBITDA to Adjusted Free Cash Flow
The Company defines “Adjusted Free Cash Flow” or “AFCF” as Net Cash Provided by Operating Activities less changes in operating assets and liabilities (as reflected on our statements of cash flows); plus transaction costs for executed acquisitions and divestitures; current tax expense (benefit); proceeds from divestitures of equipment for oil and natural gas properties; loss (gain) on disposal of assets; and less capital expenditures; bad debt expense; and other income. For this purpose, our definition of capital expenditures includes costs incurred related to oil and natural gas properties (such as drilling and infrastructure costs and lease maintenance costs) but excludes acquisition costs of oil and gas properties from third parties that are not included in our capital expenditures guidance provided to investors. Our management believes that Adjusted Free Cash Flow is an important financial performance measure for use in evaluating the performance and efficiency of our current operating activities after the impact of
accrued capital expenditures and net interest expense and without being impacted by items such as changes associated with working capital, which can vary substantially from one period to another. Other companies may use different definitions of Adjusted Free Cash Flow.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited for All Periods) |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
| Net Cash Provided by Operating Activities | $ | 55,733,207 | | | $ | 55,390,975 | | | $ | 63,641,506 | | | $ | 198,170,459 | | | $ | 196,976,729 | |
| Adjustments - Condensed Statements of Cash Flows | | | | | | | | | |
| Changes in operating assets and liabilities | (606,551) | | | (6,843,290) | | | (16,257,293) | | | (1,180,748) | | | (24,091,577) | |
| Transaction costs - executed A&D | 354,616 | | | (157,641) | | | 993,027 | | | 417,166 | | | 2,135,990 | |
| Income tax expense (benefit) - current | (192,048) | | | 165,780 | | | (36,736) | | | 72,213 | | | — | |
| Capital expenditures | (38,817,080) | | | (42,398,484) | | | (42,618,754) | | | (151,969,735) | | | (140,051,159) | |
| Proceeds from divestiture of equipment for oil and natural gas properties | — | | | — | | | (1,366) | | | 54,558 | | | 23,700 | |
| Bad debt expense | (92,142) | | | (19,656) | | | (242,247) | | | (134,007) | | | (242,247) | |
| Loss (gain) on disposal of assets | (44,981) | | | — | | | — | | | 87,128 | | | — | |
| Other income | (72,725) | | | — | | | — | | | (198,935) | | | — | |
| | | | | | | | | |
| Adjusted Free Cash Flow | $ | 16,262,296 | | | $ | 6,137,684 | | | $ | 5,478,137 | | | $ | 45,318,099 | | | $ | 34,751,436 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited for All Periods) |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
| Adjusted EBITDA | $ | 65,364,805 | | | $ | 58,579,030 | | | $ | 56,344,541 | | | $ | 235,982,139 | | | $ | 195,240,603 | |
| | | | | | | | | |
| Net interest expense (excluding amortization of deferred financing costs) | (10,285,429) | | | (10,042,862) | | | (8,246,284) | | | (38,748,863) | | | (20,461,708) | |
| Capital expenditures | (38,817,080) | | | (42,398,484) | | | (42,618,754) | | | (151,969,735) | | | (140,051,159) | |
| Proceeds from divestiture of oil and natural gas properties | — | | | — | | | (1,366) | | | 54,558 | | | 23,700 | |
| | | | | | | | | |
Adjusted Free Cash Flow | $ | 16,262,296 | | | $ | 6,137,684 | | | $ | 5,478,137 | | | $ | 45,318,099 | | | $ | 34,751,436 | |
Reconciliation of Net Cash Provided by Operating Activities to Adjusted Cash Flow from Operations
The Company defines “Adjusted Cash Flow from Operations” or “ACFFO” as Net Cash Provided by Operating Activities, per the Condensed Statements of Cash Flows, less the changes in operating assets and liabilities, including accounts receivable, inventory, prepaid expenses and other assets, accounts payable, and settlement of asset retirement obligation, which are subject to variation due to the nature of the Company’s operations. Accordingly, the Company believes this non-GAAP measure is useful to investors because it is used often in its industry and allows investors to compare this metric to other companies in its peer group as well as the E&P sector.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited for All Periods) |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
| Net Cash Provided by Operating Activities | $ | 55,733,207 | | | $ | 55,390,975 | | | $ | 63,641,506 | | | $ | 198,170,459 | | | $ | 196,976,729 | |
| | | | | | | | | |
| Changes in operating assets and liabilities | (606,551) | | | (6,843,290) | | | (16,257,293) | | | (1,180,748) | | | (24,091,577) | |
| | | | | | | | | |
Adjusted Cash Flow from Operations | $ | 55,126,656 | | | $ | 48,547,685 | | | $ | 47,384,213 | | | $ | 196,989,711 | | | $ | 172,885,152 | |
Reconciliation of General and Administrative Expense (G&A) to G&A Excluding Share-Based Compensation and Transaction Costs
The following table presents a reconciliation of General and Administrative Expense (G&A), a GAAP measure, to G&A excluding share-based compensation, and G&A excluding share-based compensation and transaction costs.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited for All Periods) |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| | | | | | | | | |
General and administrative expense (G&A) | $ | 8,164,799 | | | $ | 7,083,574 | | | $ | 8,346,896 | | | $ | 29,188,755 | | | $ | 27,095,323 | |
| Shared-based compensation | 2,458,682 | | | 2,170,735 | | | 2,198,043 | | | 8,833,425 | | | 7,162,231 | |
G&A excluding share-based compensation | 5,706,117 | | | 4,912,839 | | | 6,148,853 | | | 20,355,330 | | | 19,933,092 | |
Transaction costs - executed A&D | 354,616 | | | (157,641) | | | 993,027 | | | 417,166 | | | 2,135,990 | |
G&A excluding share-based compensation and transaction costs | $ | 5,351,501 | | | $ | 5,070,480 | | | $ | 5,155,826 | | | $ | 19,938,164 | | | $ | 17,797,102 | |
Calculation of Leverage Ratio
“Leverage” or the “Leverage Ratio” is calculated under our existing senior revolving credit facility and means as of any date, the ratio of (i) our consolidated total debt as of such date to (ii) our Consolidated EBITDAX for the four consecutive fiscal quarters ending on or immediately prior to such date for which financial statements are required to have been delivered under our existing senior revolving credit facility; provided that for the purposes of the definition of ‘Leverage Ratio’, (a) for the fiscal quarter ended September 30, 2022, Consolidated EBITDAX is calculated by multiplying Consolidated EBITDAX for such fiscal quarter by four, (b) for the fiscal quarter ended December 31, 2022, Consolidated EBITDAX is calculated by multiplying Consolidated EBITDAX for the two fiscal quarter periods ended on December 31, 2022 by two, (c) for the fiscal quarter ended March 31, 2023, Consolidated EBITDAX is calculated by multiplying Consolidated EBITDAX for the three fiscal quarter period ended on March 31, 2023 by four-thirds, and (d) for each fiscal quarter thereafter, Consolidated EBITDAX will be calculated by adding Consolidated EBITDAX for the four consecutive fiscal quarters ending on such date.
The Company defines “Consolidated EBITDAX” in accordance with our existing senior revolving credit facility and it means for any period an amount equal to the sum of (i) consolidated net income (loss) for such period plus (ii) to the extent deducted in determining consolidated net income for such period, and without duplication, (A) consolidated interest expense, (B) income tax expense determined on a consolidated basis in accordance with GAAP, (C) depreciation, depletion and amortization determined on a consolidated basis in accordance with GAAP, (D) exploration expenses determined on a consolidated
basis in accordance with GAAP, and (E) all other non-cash charges acceptable to our senior revolving credit facility administrative agent determined on a consolidated basis in accordance with GAAP, in each case for such period minus (iii) all noncash income added to consolidated net income (loss) for such period; provided that, for purposes of calculating compliance with the financial covenants set forth in our senior revolving credit facility, to the extent that during such period we shall have consummated an acquisition permitted by the senior revolving credit facility or any sale, transfer or other disposition of any person, business, property or assets permitted by the senior revolving credit facility, Consolidated EBITDAX will be calculated on a pro forma basis with respect to such person, business, property or assets so acquired or disposed of.
Also set forth in our existing senior revolving credit facility is the maximum permitted Leverage Ratio of 3.00. The following table shows the leverage ratio calculation for the Company’s most recent fiscal quarter.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited) |
| Three Months Ended | | |
| March 31, | | June 30, | | September 30, | | December 31, | | Last Four Quarters |
| 2023 | | 2023 | | 2023 | | 2023 | |
| Consolidated EBITDAX Calculation: | | | | | | | | | |
| Net Income (Loss) | $ | 32,715,779 | | | $ | 28,791,605 | | | $ | (7,539,222) | | | $ | 50,896,479 | | | $ | 104,864,641 | |
| Plus: Interest expense | 10,390,279 | | | 10,471,062 | | | 11,301,328 | | | 11,506,908 | | | 43,669,577 | |
| Plus: Income tax provision (benefit) | 2,029,943 | | | (6,356,295) | | | (3,411,336) | | | 7,862,930 | | | 125,242 | |
| Plus: Depreciation, depletion and amortization | 21,271,671 | | | 20,792,932 | | | 21,989,034 | | | 24,556,654 | | | 88,610,291 | |
| Plus: non-cash charges acceptable to Administrative Agent | (7,823,887) | | | (470,875) | | | 36,396,867 | | | (29,695,076) | | | (1,592,971) | |
| Consolidated EBITDAX | $ | 58,583,785 | | | $ | 53,228,429 | | | $ | 58,736,671 | | | $ | 65,127,895 | | | $ | 235,676,780 | |
| Plus: Pro Forma Acquired Consolidated EBITDAX | $ | 15,385,792 | | | $ | 9,542,529 | | | $ | 4,810,123 | | | $ | — | | | $ | 29,738,444 | |
| Less: Pro Forma Divested Consolidated EBITDAX | (1,346,877) | | | (357,122) | | | (672,113) | | | (67,092) | | | (2,443,204) | |
| Pro Forma Consolidated EBITDAX | $ | 72,622,700 | | | $ | 62,413,836 | | | $ | 62,874,681 | | | $ | 65,060,803 | | | $ | 262,972,020 | |
| | | | | | | | | |
Non-cash charges acceptable to Administrative Agent: | | | | | | | | | |
| Asset retirement obligation accretion | $ | 365,847 | | | $ | 353,878 | | | $ | 354,175 | | | $ | 351,786 | | | |
| Unrealized loss (gain) on derivative assets | (10,133,430) | | | (3,085,065) | | | 33,871,957 | | | (32,505,544) | | | |
| Share-based compensation | 1,943,696 | | | 2,260,312 | | | 2,170,735 | | | 2,458,682 | | | |
| Total non-cash charges acceptable to Administrative Agent | $ | (7,823,887) | | | $ | (470,875) | | | $ | 36,396,867 | | | $ | (29,695,076) | | | |
| | | | | | | | | |
| As of | | | | | | | | |
| December 31, | | | | | | | | |
| 2023 | | | | | | | | |
| Leverage Ratio Covenant: | | | | | | | | | |
Revolving line of credit | $ | 425,000,000 | | | | | | | | | |
| Pro Forma Consolidated EBITDAX | 262,972,020 | | | | | | | | | |
| Leverage Ratio | 1.62 | | | | | | | | | |
| Maximum Allowed | ≤ 3.00x | | | | | | | | |
Calculation of Current Ratio
The “Current Ratio” is calculated under our existing senior revolving credit facility and means as of any date, the ratio of (i) our Current Assets as of such date to (ii) our Current Liabilities as of such date. Based on its credit agreement, the Company defines Current Assets as all current assets, excluding non-cash assets under Accounting Standards Codification (“ASC”) 815, plus the unused line of credit. The Company’s non-cash current assets include the derivative asset marked to market value. Based on its
credit agreement, the Company defines Current Liabilities as all liabilities, in accordance with GAAP, which are classified as current liabilities, including all indebtedness payable on demand or within one year, all accruals for federal or other taxes payable within such year, but excluding current portion of long-term debt required to be paid within one year, the aggregate outstanding principal balance and non-cash obligations under ASC 815.
Also set forth in our existing senior revolving credit facility is the minimum permitted Current Ratio of 1.00. The following table shows the current ratio calculation for the Company’s most recent fiscal quarter.
| | | | | | | | |
| | As of |
| | December 31, |
| | 2023 |
| Current Assets | | 55,910,819 | |
| Less: Current derivative assets | | 6,215,374 | |
| Current Assets per Covenant | | 49,695,445 | |
| Revolver Availability (Facility less debt less LCs) | | 174,239,562 | |
| Current Assets per Covenant | | 223,935,007 | |
| | |
| Current Liabilities | | 113,808,266 | |
| Less: Current financing lease liability | | 956,254 | |
| Less: Current operating lease liability | | 568,176 | |
| Less: Current derivative liabilities | | 7,520,336 | |
| Current Liabilities per Covenant | | 104,763,500 | |
| | |
| Current Ratio | | 2.14 | |
| Minimum Allowed | | > or = 1.00x |
Calculation of Cash Return on Capital Employed
The Company defines “Return on Capital Employed” or “CROCE” as Adjusted Cash Flow from Operations divided by average debt and shareholder equity for the period. Management believes that CROCE is useful to investors as a performance measure when comparing our profitability and the efficiency with which management has employed capital over time relative to other companies. CROCE is not considered to be an alternative to net income reported in accordance with GAAP.
| | | | | | | | | | | | | | | | | |
| CROCE (Cash Return on Capital Employed): | As of and for the |
| twelve months ended |
| December 31, | | December 31, | | December 31, |
| 2023 | | 2022 | | 2021 |
| | | | | |
| Total long term debt (i.e. revolving line of credit) | $425,000,000 | | $415,000,000 | | $290,000,000 |
| Total stockholders' equity | $786,582,900 | | $661,103,391 | | $300,624,207 |
| | | | | |
| Average debt | $420,000,000 | | $352,500,000 | | $301,500,000 |
| Average stockholders' equity | 723,843,146 | | 480,863,799 | | 297,695,010 |
| Average debt and stockholders' equity | 1,143,843,146 | | 833,363,799 | | 599,195,010 |
| | | | | |
| Net Cash Provided by Operating Activities | $198,170,459 | | $196,976,729 | | $72,731,212 |
| Less change in WC (Working Capital) | 1,180,748 | | 24,091,577 | | 3,236,824 |
| Adjusted Cash Flows From Operations (ACFFO) | $196,989,711 | | $172,885,152 | | $69,494,388 |
| | | | | |
| CROCE (ACFFO)/(Average D+E) | 17.2 | % | | 20.7 | % | | 11.6 | % |
All-In Cash Operating Costs
The Company defines All-In Cash Operating Costs, a non-GAAP financial measure, as “all in cash” costs including lease operating expenses, G&A costs excluding share-based compensation (“cash G&A”), interest expense, workovers and other operating expenses, production taxes, ad valorem taxes, and gathering/transportation costs. Management believes that this metric provides useful additional information to investors to assess the Company’s operating costs in comparison to its peers, which may vary from company to company.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| (Unaudited for All Periods) |
| Three Months Ended | | Twelve Months Ended |
| December 31, | | September 30, | | December 31, | | December 31, | | December 31, |
| 2023 | | 2023 | | 2022 | | 2023 | | 2022 |
| All-In Cash Operating Costs: | | | | | | | | | |
| Lease operating expenses (including workovers) | 18,732,082 | | | 18,015,348 | | | 17,411,645 | | | 70,158,227 | | | 47,695,351 | |
G&A excluding share-based compensation | 5,706,117 | | | 4,912,839 | | | 6,148,853 | | | 20,355,330 | | | 19,933,092 | |
| Net interest expense (excluding amortization of deferred financing costs) | 10,285,429 | | | 10,042,862 | | | 8,246,284 | | | 38,748,863 | | | 20,461,704 | |
| Operating lease expense | 175,090 | | | 138,220 | | | 113,138 | | | 541,801 | | | 363,908 | |
| Oil and natural gas production taxes | 4,961,768 | | | 4,753,289 | | | 5,186,644 | | | 18,135,336 | | | 17,125,982 | |
| Ad valorem taxes | 1,637,722 | | | 1,779,163 | | | 1,570,039 | | | 6,757,841 | | | 4,670,617 | |
| Gathering, transportation and processing costs | 464,558 | | | (4,530) | | | (16,223) | | | 457,573 | | | 1,830,024 | |
| All-in cash operating costs | 41,962,766 | | | 39,637,191 | | | 38,660,380 | | | 155,154,971 | | | 112,080,678 | |
| | | | | | | | | |
| Boe | 1,784,490 | | 1,610,857 | | 1,642,715 | | 6,613,321 | | 4,512,610 |
| | | | | | | | | |
| All-in cash operating costs per Boe | $ | 23.52 | | | $ | 24.61 | | | $ | 23.53 | | | $ | 23.46 | | | $ | 24.84 | |
NYSE American: REIwww.ringenergy.com VALUE FOCUSED PROVEN STRATEGY Q4 & FY 2023 REVIEW 2024 GUIDANCE
Ring Energy, Inc. Forward –Looking Statements This Presentation includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical fact included in this Presentation, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, guidance, plans and objectives of management are forward-looking statements. When used in this Presentation, the words “could,” “may,” “will,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “guidance,” “project,” “goal,” “plan,” “potential,” “probably,” “target” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on management’s current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. However, whether actual results and developments will conform to expectations is subject to a number of material risks and uncertainties, including but not limited to: declines in oil, natural gas liquids or natural gas prices; the level of success in exploration, development and production activities; adverse weather conditions that may negatively impact development or production activities; the timing of exploration and development expenditures; inaccuracies of reserve estimates or assumptions underlying them; revisions to reserve estimates as a result of changes in commodity prices; impacts to financial statements as a result of impairment write-downs; risks related to level of indebtedness and periodic redeterminations of the borrowing base and interest rates under the Company’s credit facility; Ring’s ability to generate sufficient cash flows from operations to meet the internally funded portion of its capital expenditures budget; the impacts of hedging on results of operations; and Ring’s ability to replace oil and natural gas reserves. Such statements are subject to certain risks and uncertainties which are disclosed in the Company’s reports filed with the Securities and Exchange Commission (“SEC”), including its Form 10-K for the fiscal year ended December 31, 2023, and its other filings with the SEC. All forward-looking statements in this Presentation are expressly qualified by the cautionary statements and by reference to the underlying assumptions that may prove to be incorrect. The Company undertakes no obligation to revise these forward-looking statements to reflect events or circumstances that arise after the date hereof, except as required by applicable law. The financial and operating estimates contained in this Presentation represent our reasonable estimates as of the date of this Presentation. Neither our independent auditors nor any other third party has examined, reviewed or compiled the estimates and, accordingly, none of the foregoing expresses an opinion or other form of assurance with respect thereto. The assumptions upon which the estimates are based are described in more detail herein. Some of these assumptions inevitably will not materialize, and unanticipated events may occur that could affect our results. Therefore, our actual results achieved during the periods covered by the estimates will vary from the estimated results. Investors are not to place undue reliance on the estimates included herein. Forward-Looking Statements and Supplemental Non-GAAP Financial Measures 2 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Supplemental Non-GAAP Financial Measures This Presentation includes financial measures that are not in accordance with accounting principles generally accepted in the United States (“GAAP”), such as “Adjusted Net Income,” “Adjusted EBITDA,” “PV-10,” “Adjusted Free Cash Flow,” or “AFCF,” “Adjusted Cash Flow from Operations,” or “ACFFO,” “Cash Return on Capital Employed” or “CROCE,” “Liquidity,” “Leverage Ratio” and “All-in Cash Operating Costs.” While management believes that such measures are useful for investors, they should not be used as a replacement for financial measures that are in accordance with GAAP. For definitions of such non-GAAP financial measures and their reconciliations to GAAP measures, please see the Appendix.
Ring Energy, Inc. Independent Oil & Gas Company 3 Focused on Conventional Permian Assets in Texas Ring Energy Assets Northwest Shelf Central Basin Platform 1. SEC Proved Reserves as of 12/31/2023 utilizing SEC prices, YE 2023 SEC Pricing Oil $74.70 per bbl Gas $2.637 per Mc.f 2. PV-10 is a Non-GAAP financial measure. See Appendix for reconciliation to GAAP measure. 3. Includes all locations operated and non-operated across “PDNP” and “PUD” reserve categories and project types. Q4 2023 Net Production ~19,400 Boe/d (70% oil and 85% liquids) 2023 SEC Proved Reserves1,2 129.8 MMBoe/ PV10 ~$1.65 Billion Proved Developed ~68% Permian Basin Gross / Net Acres 96,127 / 80,535 450+ Proved Locations3 Includes operated & non-operated Differentiated approach by applying unconventional technology and thinking to conventional Permian assets Ring Assets Characteristics: ✓ Shallow Base Decline ✓ Long Life Wells (> 35 years) ✓ Highly Oil Weighted ✓ High Operating Margin ✓ High Netbacks (NRI> 80%) ✓ Low D&C Cost Inventory ✓ Low Breakevens Yoakum Gaines Andrews Ector Crane Ward High Operational Ownership ~98% Operated WI ~81% Oil NRI ~85% Gas NRI
Ring Energy, Inc. Positioning the Company to Return Capital to Stockholders 4 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI 1. Adjusted EBITDA and Adjusted Free Cash Flow (AFCF) are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. Delivering Value by Executing Strategic Vision 17 consecutive quarters of AFCF, Increased YOY AFCF by 30% and Adj EBITDA by 21% Growing AFCF and Adj EBITDA1 Adding Size and Scale Upgraded portfolio and more than doubled production through accretive acquisitions and non-core divestitures over past 18 months 3 Year Track record of reducing leverage, growing liquidity and improving financial flexibility Enhancing the Balance Sheet Driving down costs, executing a disciplined capital program and maximizing oil production safely & responsibly Pursuing Operational Excellence Key Takeaways of Value Focused Proven Strategy Value Focused Proven Strategy Clear sight to reduce debt and leverage ratio by executing disciplined organic capital program focused on maximizing AFCF Continued growth through balance sheet enhancing accretive acquisitions that help achieve the size and scale necessary to position the Company to return capital to stockholders
Ring Energy, Inc. 2023 Year-End Highlights 5 Proven Strategy Leads to Superior Results - Comparing Q4’2023 vs Q4’2022 Operating Lifting Cost Sales Boe Adjusted EBITDA1 CapEx Cash G&A Costs2 Adjusted Free Cash Flow1 Leverage Ratio3 19,397 Boe/d Q4 2023 $10.50 Per Boe Q4 2023 17,856 Boe/d Q4 2022 1. Adjusted EBITDA, and Adjusted Free Cash Flow are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. 2. Cash G&A excluding stock-based compensation on $ per Boe basis. 3. Leverage Ratio is defined in Appendix. 4. “PD” Proved Developed Reserves as of 12/31/2023 utilizing SEC prices, YE 2023 SEC Pricing Oil $74.70 per bbl Gas $2.637 per Mcf. $65.4 Million Q4 2023 $38.8 Million Q4 2023 $16.3 Million Q4 2023 1.62x Ratio Q4 2023 $3.20 Per Boe Q4 2023 $10.60 Per Boe Q4 2022 $56.3 Million Q4 2022 $42.6 Million Q4 2022 $3.74 Per Boe Q4 2022 1.56x Ratio Q4 2022 $5.5 Million Q4 2022 Company record Sales Bo 13,637 Bo/d Q4 2023 12,189 Bo/d Q4 2022 Debt Balance $425 Million Q4 2023 $415 Million Q4 2022 SEC PD Reserves4 88,128 MBoe Q4 2023 90,078 MBoe Q4 2022 Company record Company record Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI
Ring Energy, Inc. Expanding Core Areas in NWS & CBP 6 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Acquisition Track Record • Since 2018, Ring has successfully grown production by a ~26% CAGR1 through 4Q 2023 • Founders Acquisition added accretive near-term cash flows combined with 5+ years of high return drilling inventory assuming 10 wells drilled per year • Recent acquisitions have significantly increased size & scale, positioning the Company for future transactions • Ring’s Value Focused Proven Strategy pursuing accretive, balance sheet enhancing acquisitions is a key component of our future growth 1 CAGR is compounded annualized growth rate. 2 Acquired proved reserves for each of the transactions listed are based on the price forecasts reported as of the time the acquisition was announced. 3 Arithmetic sum, or average, as the case may be, of the three acquisitions. 4 Acquisition price at announcement including stock value at announcement. Year Completed 2019 2022 2023 Total Acquired Acquired Proved Reserves (MMBoe)2 34.3 66.6 9.2 110.1 % Oil 80% 54% 80% 75%3 Acquired Net Acreage ~37,000 ~37,000 ~3,600 ~77,600 Acquisition Price4 ($MM) $300 $465 $75 $840 Consideration Mix (% Cash / % Stock) 90% / 10% 51% / 49% 100% / 0% 68% / 32% 2018A Daily Production (Boe/d) Wishbone Acquisition Stronghold Acquisition Founders Acquisition Q4 2023 Daily Production (Boe/d) New Management as of October 2020 6,100 ~19,400 Acreage includes operated and Non-Operated WI
Ring Energy, Inc. NWS CBP-N Penwell CBP-S 19% 63% 18% Highly Oil Weighted Proved Reserves1 and Inventory 7 SEC YE 2023 Reserves by Category (%) Reserves by PV-102 ($MM) Reserves by Product (%) Locations by Area PD ~88 MMBoe PUD ~42 MMBoe Significant Increase in Proved Reserves and Inventory from Stronghold & Founders Acquisitions Provides Sustainable Future Growth and Capital Allocation Flexibility 32% 68% ~130 MMBoe 23% 77% 1. Reserves as of December 31, 2023 utilizing SEC prices, YE 2023 SEC Pricing Oil $74.70 per bbl Gas $2.637 per Mcf. 2. PV-10 is a Non-GAAP financial measure. See Appendix for reconciliation to GAAP measure. 3. Includes all locations operated and non-operated across “PDNP” and “PUD” reserve categories and project types. 4. Based on FY 2023 production rate. $1,647 $MM PD $1,263 MM PUD $384 MM Oil 82 MMBoe Gas 25 MMBoe NGL 23 MMBoe ~130 MMBoe 19.6 Year Proved Reserve Life4 210+ PUD Locations 240+ PDNP Opportunities 450+3 Total Gross Locations & Opportunities Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI
Ring Energy, Inc. 0.025 0.030 0.035 0.040 2022 2023 $20 $21 $22 $23 $24 $25 $26 $27 $28 $29 $30 2022 2023 Enhancing Value for Stockholders 8 Executing Strategy Improves YOY Production and Operating Cost per Boe Metrics Production/Share Boe/Share 0.034 0.032 Up 6% 1. All-in-Cash operating costs is defined as cash costs including LOE, cash G&A, interest expense, workovers and other operating expenses, production taxes and gathering/transportation costs. 2. Cash G&A excluding stock-based compensation on $ per Boe basis. Cash G&A Expense2 $/Boe $23.46 $24.84 $- $1 $2 $3 $4 $5 2022 2023 Down 30% All-in-Cash Operating Costs1 $/Boe $23.46 $24.84 Down 6% $4.42 $3.08 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI
Ring Energy, Inc. 0% 2% 4% 6% 8% 10% 12% 14% 16% 18% 20% 2022 2023 Enhancing Value for Stockholders Continued… 9 Executing Strategy Improves Key YOY Cash Flow Metrics Free Cash Flow Yield2 % 10% 16% $160 $165 $170 $175 $180 $185 $190 $195 $200 2022 2023 ACFFO1 $MM $197 $173 0% 25% 50% 75% 3Q22 YTD 3Q23 YTD Adjusted EBITDA Margin1 57% 65% Up 16% % 2022 2023 Up 14% Up 58% 1. Adjusted Free Cash Flow and Adjusted EBITDA margin are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. 2. Free Cash Flow Yield is (Adjusted Free Cash Flow divided by market cap for the period) with market cap calculated by multiplying weighted average diluted share count by year-end share price for the period. Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI
Ring Energy, Inc. $ 7 .0 4 $ 9 .8 9 $ 1 0 .0 2 $ 1 6 .0 9 $ 1 7 .6 4 $ 1 7 .6 4 $ 1 8 .8 3 $ 2 6 .1 7 $ 3 0 .4 5 $ 3 4 .8 8 $37.72 $43.33 $41.03 $29.30 $72.25 $43.33 $42.86 $43.82 $54.07 $55.20 $0 $10 $20 $30 $40 $50 $60 $70 $80 Peer 1 Peer2 Peer 3 Peer 4 Peer 5 Median Peer 6 Peer 7 REI Peer 8 $ /B O E Cash Operating Margin Realized Pricing Strong Cash Operating Margins vs. Peers1,2 10 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Operational Excellence and Cost Control Drive Profitability YTD Q3 2023 Cash Operating Margin and Realized Pricing Top Quartile Cash Operating Margin • High oil weighting of ~70% (85% mix of oil + liquids) contributes to high realized pricing per Boe • Low cash operating costs and maintaining cost discipline drive margin expansion • Generating over $30 per Boe in margin YTD Q3 2023 demonstrates strength of long-life asset base • Strong cash operating margins allow the Company to withstand volatile commodity price swings • Robust margins lead to increased cash flow, debt reduction and stronger returns “ Improving operational margins leads to higher returns...pursuing strategic acquisitions of high margin assets leads to sustainable higher returns “ - Paul McKinney 1. Peers include: Amplify Energy, Battalion, Berry Corporation, Crescent Energy, Riley Permian, SilverBow Resources, Vital Energy and W&T Offshore. 2. Source information for data obtained from Peer Reports and Capital IQ and Factset as of 11/29/23. 3. Cash Operating Margins are defined as revenues (excluding hedges) less LOE, cash G&A, interest expense, workovers and other operating expenses, production taxes and gathering/transportation costs. 3
Ring Energy, Inc. Enhancing Value for Stockholders 11 Track Record of Improving Corporate Returns $39.16 $68.13 $94.90 $77.58 $0 $10 $20 $30 $40 $50 $60 $70 $80 $90 $100 0% 5% 10% 15% 20% 25% 30% 2020 2021 2022 2023 Cash Return on Capital Employed1 (CROCE) % AVG WTI Pricing $/Bbl 17.2% 20.7% Strong CROCE % • Disciplined and successful capital program driving returns • Generating solid returns by benefitting from a shallower decline production base and strong sustained oil pricing • High quality asset base and inventory together with operating proficiency led to a capital efficient program • Multiple asset core areas in NWS & CBP with existing infrastructure along with diverse inventory of high return, low cost D&C horizontals and verticals provide flexibility to react to volatile market conditions Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI 1. The Company defines “CROCE” as Adjusted Cash Flow from Operations divided by average debt and shareholder equity for the period. 11.6% 9.3% 2020 – 2022 CROCE Avg of 13.9% Up 24% vs 2020-’22 AVG
Ring Energy, Inc. Compelling Value Proposition 1,2 12 -15% -10% -5% 0% 5% 10% 15% 20% 25% 30% 35% 0.0x 1.0x 2.0x 3.0x 4.0x 5.0x 6.0x 7.0x 0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100% 0.0x 0.2x 0.4x 0.6x 0.8x 1.0x 1.2x 1.4x 1.6x % O il EV /P V -1 0 EV/2023E Adjusted EBITDA3EV/PV-103 YE23 1P Reserves & % Oil 2023E Adjusted FCF3,4 Yield Ring Currently Trades at a Discount to Peers, Despite a Track Record of Success Including Strong Returns, Significant Cash Flow, Improved Balance Sheet and Meaningful Growth 1. Peers include: Berry Corporation, Crescent Energy, HighPeak Energy, Permian Resources, Riley Permian, SilverBow Resources, Vital Energy and W&T Offshore. 2. Source information for data obtained from Peer Reports and Capital IQ and Factset as of 3/6/24. 3. Adjusted EBITDA, Adjusted FCF and PV-10 are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. 4. Adjusted free cash flow yield is defined as adjusted free cash flow divided by market cap for the period with market cap calculated by multiplying weighted average diluted share count by year-end share price. Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI
Ring Energy, Inc. 18,119 18,500 17,000 18,000 19,000 12,548 12,950 12,000 13,000 14,000 16% 11% 21% 30% 0% 10% 20% 30% 40% 50% $0 $20 $40 $60 $80 $100 A F C F Y ie ld % A F C F $ M M Positioned for Success in 2024 & Beyond 13 1. Estimated Adjusted FCF is based on internal management financial model and assumes mid point of guidance for Net Sales production and capex with applicable oil price, 3/4/2024 gas HH strip price (Feb-Dec 2024 Avg $2.51 per Mcf) and NGL realization of 22% of WTI oil price. 2. Estimated AFCF yield is based on assumptions above and Ring’s stock price and market capitalization as 3/4/2024. Pursue Operational Excellence with an Emphasis on Oil Production Growth Net Sales Oil 12,700 to 13,100 Bo/d Mid-point 12,900 Bo/d Total 18,000 to19,000 Boe/d Mid-point 18,500 Boe/d Sales Boe/dOil Sales Bo/d 2023 2024E Up ~3% Up ~2% Disciplined Capital Investment Capex $135 to $175 Million Mid-point $155 Million Capital Projects: 18-24 Horizontal & 20-30 Vertical wells Focus on Maximizing FCF Adjusted Free Cash Flow1 (Expected continued growth) $152 $155 $135 $145 $155 $165 $175 2023 2024E Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI $90 WTI 2024E $80 WTI$70 WTI 2023 2024E 2023 Current 2024 Outlook
Ring Energy, Inc. Compelling Value Proposition1,2 14 -5% 0% 5% 10% 15% 20% 25% 30% 35% 40% 0.0x 0.5x 1.0x 1.5x 2.0x 2.5x 3.0x 3.5x 4.0x 4.5x 5.0x EV/2024E Adjusted EBITDA3 2024E Adjusted FCF3,4 Yield Ring Currently Trades at a Discount to Peers, Despite Superior 2024 Consensus Estimates 1. Peers include: Berry Corporation, Crescent Energy, HighPeak Energy, Permian Resources, Riley Permian, SilverBow Resources, Vital Energy and W&T Offshore. 2. Source information for data obtained from Peer Reports and Capital IQ and Factset as of 3/6/24 with 2024 avg WTI pricing of $77 per Bbl of oil. 3. Adjusted EBITDA and Adjusted FCF are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. 4. Free cash flow yield is defined as adjusted free cash flow divided by market cap for the period with market cap calculated by multiplying weighted average diluted share count by year-end share price. Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI
Ring Energy, Inc. Value Proposition 15 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI 2024 and Beyond Trading at a discount yet delivering competitive returns Target getting leverage below 1.0x and position Ring to return capital to stockholders Despite volatile energy markets, Ring has generated positive FCF for 17 quarters straight Strong Cash Operating margins help deliver superior results & helps manage risk in market downturns Disciplined capital program focused on slightly increasing oil production, and maximizing FCF generation leads to further debt reduction Pursuing accretive, balance sheet enhancing acquisitions to increase scale, lower break-even costs, build inventory and accelerate ability to pay down debt
Ring Energy, Inc. Committed to ESG 16 Critical to Sustainable Success 2023 Sustainability Report Progressing our ESG Journey A Target Zero Day is a Day that Results in: Zero Company or Contractor OSHA Recordable Injury, and Zero Agency Reportable Spill or Release as Defined by TRRC, EPA, TCEQ, etc., and Zero Preventable Vehicle Incidents, and Zero Unintentional Natural Gas Releases Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI • Created ESG Task Force in 2021 to monitor Company’s adherence to ESG standards and formally communicate to CEO and the Board on ongoing basis. • Established Target Zero 365 (TZ-365) Safety & Environmental Initiative in 2021 to further build culture for employees to work safely, openly communicate incidents, near misses, and strive for continuous improvement. – Designed to protect workforce, environment, communities and financial sustainability. – Focused on Safety-first environment and achieving high percentage of Target Zero Days. • 2024 Capital Program includes Fugitive Emission Reduction plans with: – Installation of Vapor Recovery Units. – Installation of Air Compression Equipment to operate Pneumatic Actuators. – Establishing Leak Detection and Repair program. • Refreshed all charters, guidelines and bylaws. • Increased charitable giving and employee outreach within the communities in which we live and work. Download Report PDF
www.ringenergy.com FINANCIAL OVERVIEW 17
Ring Energy, Inc. Q1 & FY 2024 Guidance 18 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Grow Oil Production, Generate FCF, Pay Down Debt FY 2024 CAPEX Allocation D,C&E Recomp/Cap Workovers Land/Non-op/Other $155 million Mid Point 73% 24% 3% Sales Volumes Q1 2024 FY 2024 Total (Bo/d) 12,420 – 12,765 12,600 – 13,300 Mid Point (Bo/d) 12,593 12,950 Total (Boe/d) 18,000 – 18,500 18,000 – 19,000 - Oil (%) 69% 70% - NGLs (%) 15% 15% - Gas (%) 16% 15% Capital Program Capital spending1 (millions) $37 – $42 $135 – $175 Mid Point (millions) $39.5 $155 - New Hz wells drilled 4 – 5 18 – 24 - New Vertical wells drilled 4 – 6 20 – 30 - Wells completed and online 8 – 10 38 – 54 Operating Expenses LOE (per Boe) $10.75 – $11.25 $10.50 – $11.50 1. In addition to Company-directed drilling and completion activities, the capital spending outlook includes funds for targeted well recompletions, capital workovers, and infrastructure upgrades. Also included is anticipated spending for leasing acreage, and non-operated drilling, completion, and capital workovers.
Ring Energy, Inc. 1.56x2 Q4 2022 1.65x2 Q1 2023 1.64x2 Q2 2023 1.69x2 Q3 2023 Historical Metrics 19 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Quarterly Analysis of AFCF1 Leverage Ratio (LTM)2 Disciplined and Efficient Capital Spending Focused on Sustainably Generating AFCF Enhances Our Unrelenting Goal to Strengthen the Balance Sheet 1. Adjusted EBITDA and Adjusted Free Cash Flow are Non-GAAP financial measures. See Appendix for reconciliation to GAAP measures. 2. See Appendix for reconciliation. The Q3 2023 Leverage Ratio of 1.69x included $11.9 million deferred cash payment paid in December 2023 for the Founders Acquisition. Excluding the deferred payment in the calculation results in a Leverage Ratio of 1.64x. 3. Interest Expense included in table excludes deferred financing costs amortization. $56.3 $58.6 $53.5 $58.6 $65.4 -$42.6 -$38.9 -$31.6 -$42.4 -$38.8 -$8.2 -$9.2 -$9.3 -$10.0 -$10.3 $5.5 $10.5 $12.6 $6.1 $16.3 -$50 -$40 -$30 -$20 -$10 $0 $10 $20 $30 $40 $50 $60 $70 $80 A d j. E B IT D A / C a p E x / In t E x p Adj EBITDA $MM CapEx $MM Net Interest Exp $MM Adj. Free Cash Flow $MM 1.62x2 Q4 2023 3
Ring Energy, Inc. Reducing Debt & Increasing Liquidity 20 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Disciplined Capital Spending & Sustainably Generating AFCF Adjusted Debt Paydown1,2 ($ Million) Liquidity3 ($ Million) 1. Paydown of $17 million is net of the $182 million that was borrowed to fund the Stronghold acquisition. 2. Paydown of $19 million is net of the $50 million that was borrowed to fund the Founders acquisition. 3. Liquidity is defined as cash and cash equivalents plus available borrowings under Ring’s credit agreement. $8 $5 $6 $5 $10 $10 $17 $20 -$7 $25 $19 $3 -$10 -$5 $0 $5 $10 $15 $20 $25 $30 Q1'21 Q2'21 Q3'21 Q4'21 Q1'22 Q2'22 Q3'22 Q4'22 Q1'23 Q2'23 Q3'23 Q4'23 Stronghold Acquisition1 Stronghold Acquisition final deferred payment $46 $51 $56 $62 $71 $82 $165 $188 $179 $204 $171 $175 $0 $20 $40 $60 $80 $100 $120 $140 $160 $180 $200 $220 Q1'21 Q2'21 Q3'21 Q4'21 Q1'22 Q2'22 Q3'22 Q4'22 Q1'23 Q2'23 Q3'23 Q4'23 Stronghold Acquisition Founders Acquisition2 Founders Acquisition Founders Acquisition final deferred payment
www.ringenergy.com ASSET OVERVIEW
Ring Energy, Inc. Assets Overview 22 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Core Assets in NWS & CBP 1. Reserves as of 12/31/23 utilizing SEC prices, YE 2023 SEC Pricing Oil $74.70 per bbl and Gas $2.64 per Mcf, PV-10 is a Non-GAAP financial measure. See Appendix for reconciliation to GAAP measure. Q4 2023 Net Production (MBoe/d) ~19.4 NWS (76% oil) CBP (66% oil) ~8.0 ~11.4 LOE ($ per Boe) $10.50 Capex ($MM) $38.8 YE23 PD Reserves1 PV10 ($MM) $1,263 YE23 PD Reserves1 (MMBoe) 88 YE23 PUD Reserves1 PV10 ($MM) $384 YE23 PUD Reserves1 (MMBoe) 42 Northern CBP Southern CBPIncludes operated & Non-operated
Ring Energy, Inc. Assets Overview 23 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Historical Quarterly Net Sales Production1 1. Source is factset quarterly financials. Q3 Stronghold AQ – moved to 3 stream 6,779 7,719 7,166 7,774 7,514 8,016 10,139 12,189 12,660 11,861 12,028 1,181 991 1,078 1,380 1,356 1,325 1,726 3,044 2,966 2,853 2,839 1,414 2,623 2,667 2,557 2,643 0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000 18,000 20,000 Q1 '21 Q2 '21 Q3 '21 Q4 '21 Q1 '22 Q2 '22 Q3 '22 Q4 '22 Q1 '23 Q2 '23 Q3 '23 Q4 '23 N e t O il S a le s B o p d + G a s S a le s B o e p d + N G L S a le s B o e p d Company Oil Bopd Company Gas Boepd Company NGL Boepd 2021 “phased drilling” Total 13 Hz 2022 “continuous drilling” Total 27 Hz & 7 Vert. Company Record Production 19,397 DLWR Sale & pullback in capex spend in anticipation of Founders AQ Founders AQ Closed 8/15 & New Mexico Sale 1H 2023 “phased drilling” 8 Hz & 5 Vert. 2H 2023 “continuous drilling” 12 Hz & 6 Vert. 2,837 13,637 2,922 Capital allocation and drilling programs designed to maximize free cashflow generation Gaines Co Sale Oil Bopd Gas Boepd NGL Boepd
Ring Energy, Inc. Assets Overview 24 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI New Drill Inventory Performance Consistent HZ Well Performance San Andres Horizontal Play 1 Consistent Vertical Well Performance CBP Vertical Multi-Stacked Play 2 Expected Capex Range 2024 73% Oil 86-91% Oil 65-70% Oil 72-76% Oil Expected Capex Range 2024 1. San Andres Horizontal includes the average well performance for the peak 90 days (gross BOE) for development wells in both the CBP & NWS area each year included 2021-2022 (37) and 2023 (9). Excludes delineation step out wells. 2. CBP Vertical Multi Stacked Pay Horizontal includes the average well performance for the first 90 days (gross BOE) for development wells in Southern CBP 2021-2022 (30) and 2023 (11). Excludes delineation step out wells.
Ring Energy, Inc. Assets Overview 25 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Capitalizing on High-Return Drilling and Recompletion Locations Select Recent New Drill Vertical Well Results – Central Basin Platform 1. Vertical completion no lateral length noted. 2. Initial Peak IP 60 (Boepd) based on best rolling 60-day average. 3. Initial Peak IP 30 (Boepd) based on best continuous rolling 30-day average, due to lack of 60 day production data. Select Recent Recompletion Well Results – Central Basin Platform Select Recent New Drill Horizontal Well Results – Northwest Shelf Select Recent New Drill Horizontal Well Results – Central Basin Platform Includes operated & NonOP Geological Region Area Well Name Peak IP 30 / 60 (Boepd) Oil (%) WI (%) CBP PJ Lea Lea, P J Etal #3902M1,2 273 88% 100% CBP PJ Lea Lea, P J Etal #3903M1,2 257 94% 100% CBP McKnight McKnight, M B #0201G1,2 166 65% 100% CBP McKnight McKnight, M B #0202G1,2 129 66% 100% CBP CBPS UL 35 1401S1,2 151 71% 100% CBP PJ Lea PJ Lea #3907M1,2 186 75% 100% CBP PJ Lea PJ Lea #4603M1,2 105 77% 100% CBP PJ Lea PJ Lea #4701M1,2 211 80% 100% CBP PJ Lea PJ Lea #4006M1,2 239 77% 100% CBP PJ Lea PJ Lea #4007M1,2 276 82% 100% CBP PJ Lea PJ Lea #3910M1,2 214 73% 100% 2 0 2 2 2 0 2 3 Geological Region Area Well Name Peak IP 60 (Boepd) Oil (%) WI (%) CBP McKnight McKnight, M B #2131,2 142 65% 100% CBP McKnight McKnight, M B #1571,2 84 91% 100% CBP McKnight McKnight, M B #2011,2 132 65% 100% CBP McKnight McKnight, M B #2321,2 99 76% 100% CBP McKnight McKnight, M B #0101S1,2 74 59% 100% CBP McKnight McKnight, M B #1111,2 93 52% 100% CBP McKnight McKnight, M B #1561,2 84 62% 100% 2 0 2 2 2 0 2 3 Geological Region Area Well Name Peak IP 30 / 60 (Boepd) Oil (%) Lateral Length (ft) WI (%) NWS Platang Boomer 727 #3H2 350 96% 5058 100% NWS Platang Bucky 711 C #3H2 336 92% 5038 91% NWS Platang Wishbone Farms 710 #6H2 369 93% 4277 75% NWS Platang Razorback 663 #1H2 518 90% 5058 87% NWS Platang Sooner 662 C #2H2 592 93% 4860 100% NWS Sable Horned Frog 400 C #2XH2 263 84% 7499 99% NWS Platang Cowboy Joe 708 4XH2 505 84% 7041 95% NWS Platang Longhorn 708 3XH2 432 80% 7735 75% NWS Platang Boomer 727 B 2XH2 288 76% 7628 75% NWS Platang Longhorn 708 15XH2 459 81% 7735 75% NWS Platang Reveille 644 B #2H2 304 88% 5053 100% NWS Platang Wishbone Farms 710 #4H2 451 86% 4463 75% NWS Sable Freddy Falcon 360 3H2 232 93% 4882 90% 2 0 2 3 2 0 2 2 Geological Region Area Well Name Peak IP 30 / 60 (Boepd) Oil (%) Lateral Length (ft) WI (%) CBP UL Lands University Block 14 Cons. #2001XH 527 95% 7562 100% CBP UL Lands University Block 14 Cons. #2503XH 250 95% 7386 100% CBP UL Lands University Block 14 Cons. #2006XH 327 95% 7702 100% CBP UL Lands University Block 14 Cons. #1903H 576 95% 5050 100% CBP UL Lands Zena WP 2XH2 228 88% 7730 100% CBP UL Lands University Block 14 Cons. #2501XH2 279 87% 7387 100% CBP UL Lands Hebe 1H2 247 97% 5062 100% CBP UL Lands University Block 14 Cons 2506XH2 277 86% 3665 100% 2 0 2 3 2 0 2 2
Ring Energy, Inc. Assets Overview 26 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Central Basin Platform 1 Other CBP includes the average well performance of 2022 vertical new wells drilled in Ector and Crane Counties not operated by Ring or Founders (“FOG”). The source for the Other CBP performance information was the Texas Railroad Commission. REI performance includes the average well performance of 2022 vertical new wells drilled in McKnight and PJ Lea fields and includes previously drilled Stronghold vertical wells. FOG performance includes the average well performance of 2022 vertical new wells drilled in Ector County. The source for the performance information for REI and FOG wells is Ring Energy, Inc. High Quality Inventory • Inventory of 50+ low risk, high rate-of-return drilling locations lowers Ring’s break-even costs • Recent Founders’ vertical wells demonstrate superior initial performance to other recently drilled vertical wells in Ector and northern Crane counties • High oil cuts of the Founders’ assets and inventory improve Ring’s 2024 guidance commodity mix to ~70% Oil 40 acre spacing 20 acre spacing 50+ Gross Locations Increased High Quality Inventory Inventory Breakdown Attractive Assets & Production 2022 CBP Vertical Production1 64% Oil 64-82% Oil >90% Oil 0 5,000 10,000 15,000 20,000 25,000 Other CBP REI FOG G ro ss C u m 1 8 0 -D ay /W el l A vg ., Tw o -S tr ea m B O E D&C Capex: $1.3 – 1.6MM $1.85 - 2.1MM Locations include 1P, 2P & 3P Penwell Area (Founders) Inventory of High-Return Locations Compete for Capital in 2024
Ring Energy, Inc. San Andres Reservoir 27 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Proven, Conventional, Top Tier Returns San Andres Hz Delaware Hz Midland Hz High ROR Oil Play ✓ ✓ ✓ Low D&C Costs ✓ Lower 1st Year Decline ✓ Low Lease Acquisition Cost ✓ Long life wells ✓ Oil IPs >750 Bbl/d ✓ ✓ Multiple Benches ✓ ✓ > 85% Oil ✓ $30-35/Bbl D&C Break-even2 ✓ 1. D&C capex range is for both 1.0 & 1.5 mile laterals and includes inflation adjustments. 2. Break-even costs is for core inventory in NWS & CBP asset areas. The range in break-even depends on lateral length, asset area and inflation adjustments. • Permian Basin has produced >30 BBbl — San Andres accounts for ~40% • Low D&C costs1 $3.0 - $4.4 MM per well • Vertical depth of ~5,000’ • Typical oil column of 200’ - 300’ • Life >35+ years • Initial peak oil rates of 300 - 700 Bbl/d • Higher primary recovery than shales • Potential for waterflood and CO2 flood
www.ringenergy.com APPENDIX
Ring Energy, Inc. Financial Overview 29 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Derivative Summary as of December 31, 2023 1. The oil basis swap hedges are calculated as the fixed price (weighted average spread price above) less the difference between WTI Midland and WTI Cushing, in the issue of Argus Americas Crude. Gas Hedges (Henry Hub) Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 NYMEX Swaps: Hedged volume (MMBtu) 101,615 138,053 121,587 644,946 616,199 591,725 285,200 — Weighted average swap price $ 3.62 $ 3.61 $ 3.59 $ 4.45 $ 3.78 $ 3.43 $ 3.73 $ — Two-way collars: Hedged volume (MMBtu) 417,000 605,150 584,200 27,600 27,000 27,300 308,200 598,000 Weighted average put price $ 3.94 $ 3.94 $ 3.94 $ 3.00 $ 3.00 $ 3.00 $ 3.00 $ 3.00 Weighted average call price $ 6.15 $ 6.16 $ 6.17 $ 4.15 $ 4.15 $ 4.15 $ 4.75 $ 4.15 Oil Hedges (WTI) Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Swaps: Hedged volume (Bbl) 170,625 156,975 282,900 368,000 — — 184,000 — Weighted average swap price $ 67.40 $ 66.40 $ 65.49 $ 68.43 $ — $ — $ 73.35 $ — Deferred premium puts: Hedged volume (Bbl) 45,500 45,500 — — — — — — Weighted average strike price $ 84.70 $ 82.80 $ — $ — $ — $ — $ — $ — Weighted average deferred premium price $ 17.15 $ 17.49 $ — $ — $ — $ — $ — $ — Two-way collars: Hedged volume (Bbl) 371,453 334,947 230,000 128,800 474,750 464,100 225,400 404,800 Weighted average put price $ 64.27 $ 64.32 $ 64.00 $ 60.00 $ 57.06 $ 60.00 $ 65.00 $ 60.00 Weighted average call price $ 79.92 $ 79.16 $ 76.50 $ 73.24 $ 75.82 $ 69.85 $ 78.91 $ 75.68 Oil Hedges (basis differential) Q1 2024 Q2 2024 Q3 2024 Q4 2024 Q1 2025 Q2 2025 Q3 2025 Q4 2025 Argus basis swaps: Hedged volume (Bbl) 240,000 364,000 368,000 368,000 270,000 273,000 276,000 276,000 Weighted average spread price (1) $ 1.15 $ 1.15 $ 1.15 $ 1.15 $ 1.00 $ 1.00 $ 1.00 $ 1.00
Ring Energy, Inc. Income Statement and Operational Stats 30 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Income Statement Operational Stats 1. Beginning July 1, 2022, revenues were reported on a three-stream basis, separately reporting crude oil, natural gas, and natural gas liquids volumes and sales. For periods prior to July 1, 2022, volumes and sales for natural gas liquids were presented with natural gas. 2. Boe is determined using the ratio of six Mcf of natural gas to one Bbl of oil (totals may not compute due to rounding.) The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, natural gas, and natural gas liquids may differ significantly. (Unaudited) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Oil, Natural Gas, and Natural Gas Liquids Revenues $ 99,942,718 $ 93,681,798 $ 99,697,682 $ 361,056,001 $ 347,249,537 Costs and Operating Expenses Lease operating expenses 18,732,082 18,015,348 17,411,645 70,158,227 47,695,351 Gathering, transportation and processing costs 464,558 (4,530) (16,223) 457,573 1,830,024 Ad valorem taxes 1,637,722 1,779,163 1,570,039 6,757,841 4,670,617 Oil and natural gas production taxes 4,961,768 4,753,289 5,186,644 18,135,336 17,125,982 Depreciation, depletion and amortization 24,556,654 21,989,034 20,885,774 88,610,291 55,740,767 Asset retirement obligation accretion 351,786 354,175 365,747 1,425,686 983,432 Operating lease expense 175,090 138,220 113,138 541,801 363,908 General and administrative expense (including share-based compensation) 8,164,799 7,083,574 8,346,896 29,188,755 27,095,323 Total Costs and Operating Expenses 59,044,459 54,108,273 53,863,660 215,275,510 155,505,404 Income (Loss) from Operations 40,898,259 39,573,525 45,834,022 145,780,491 191,744,133 Other Income (Expense) Interest income 96,984 80,426 — 257,155 4 Interest (expense) (11,603,892) (11,381,754) (9,468,684) (43,926,732) (23,167,729) Gain (loss) on derivative contracts 29,250,352 (39,222,755) (19,330,689) 2,767,162 (21,532,659) Gain (loss) on disposal of assets 44,981 — — (87,128) — Other income 72,725 — — 198,935 — Net Other Income (Expense) 17,861,150 (50,524,083) (28,799,373) (40,790,608) (44,700,384) Income (Loss) Before Provision for Income Taxes 58,759,409 (10,950,558) 17,034,649 104,989,883 147,043,749 Benefit from (Provision for) Income Taxes (7,862,930) 3,411,336 (2,541,980) (125,242) (8,408,724) Net Income (Loss) $ 50,896,479 $ (7,539,222) $ 14,492,669 $ 104,864,641 $ 138,635,025 Basic Earnings (Loss) per share $ 0.26 $ (0.04) $ 0.09 $ 0.55 $ 1.14 Diluted Earnings (Loss) per share $ 0.26 $ (0.04) $ 0.08 $ 0.54 $ 0.98 Basic Weighted-Average Shares Outstanding 195,687,725 195,361,476 162,743,445 190,589,143 121,264,175 Diluted Weighted-Average Shares Outstanding 197,848,812 195,361,476 178,736,799 195,364,850 141,754,668 Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Net sales volumes: Oil (Bbls) 1,254,619 1,106,531 1,121,371 4,579,942 3,459,840 Natural gas (Mcf)(1) 1,613,102 1,567,104 1,680,401 6,339,158 4,088,642 Natural gas liquids (Bbls)(1) 261,020 243,142 241,277 976,852 371,329 Total oil, natural gas and natural gas liquids (Boe)(2) 1,784,490 1,610,857 1,642,715 6,613,321 4,512,610 % Oil 70 % 69 % 68 % 69 % 77 % % Natural gas 15 % 16 % 17 % 16 % 15 % % Natural gas liquids 15 % 15 % 15 % 15 % 8 % Average daily sales volumes: Oil (Bbls/d) 13,637 12,028 12,189 12,548 9,479 Natural gas (Mcf/d)(1) 17,534 17,034 18,265 17,368 11,202 Natural gas liquids (Bbls/d)(1) 2,837 2,643 2,623 2,676 1,017 Average daily equivalent sales (Boe/d) 19,397 17,509 17,856 18,119 12,364 Average realized sales prices: Oil ($/Bbl) 77.33 81.69 81.62 76.21 92.80 Natural gas ($/Mcf)(1) -0.12 0.36 2.39 0.05 4.57 Natural gas liquids ($/Bbls)(1) 11.92 11.22 17.21 11.95 20.18 Barrel of oil equivalent ($/Boe) 56.01 58.16 60.69 54.60 76.95 Average costs and expenses per Boe ($/Boe): Lease operating expenses 10.50 11.18 10.60 10.61 10.57 Gathering, transportation and processing costs 0.26 0.00 -0.01 0.07 0.41 Ad valorem taxes 0.92 1.10 0.96 1.02 1.04 Oil and natural gas production taxes 2.78 2.95 3.16 2.74 3.80 Depreciation, depletion and amortization 13.76 13.65 12.71 13.40 12.35 Asset retirement obligation accretion 0.20 0.22 0.22 0.22 0.22 Operating lease expense 0.10 0.09 0.07 0.08 0.08 G&A (including share-based compensation) 4.58 4.40 5.08 4.41 6.00 G&A (excluding share-based compensation) 3.20 3.05 3.74 3.08 4.42 G&A (excluding share-based compensation and transaction costs) 3.00 3.15 3.14 3.01 3.94
Ring Energy, Inc. Balance Sheet and Cash Flow Statement 31 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Balance Sheet Cash Flow (Unaudited) (Unaudited) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Cash Flows From Operating Activities Net income (loss) $ 50,896,479 $ (7,539,222) $ 14,492,669 $ 104,864,641 $ 138,635,025 Adjustments to reconcile net income (loss) to net cash provided by operating activities: Depreciation, depletion and amortization 24,556,654 21,989,034 20,885,774 88,610,291 55,740,767 Asset retirement obligation accretion 351,786 354,175 365,747 1,425,686 983,432 Amortization of deferred financing costs 1,221,479 1,258,466 1,222,400 4,920,714 2,706,021 Share-based compensation 2,458,682 2,170,735 2,198,043 8,833,425 7,162,231 Bad debt expense 92,142 19,656 242,247 134,007 242,247 Deferred income tax expense (benefit) 7,735,437 (3,585,002) 2,890,984 (425,275) 8,720,992 Excess tax expense (benefit) related to share-based compensation 319,541 7,886 (312,268) 478,304 (312,268) (Gain) loss on derivative contracts (29,250,352) 39,222,755 19,330,689 (2,767,162) 21,532,659 Cash received (paid) for derivative settlements, net (3,255,192) (5,350,798) (13,932,072) (9,084,920) (62,525,954) Changes in operating assets and liabilities: Accounts receivable 6,825,601 (14,419,854) 4,086,757 1,154,085 (17,214,150) Inventory (588,100) 1,778,460 (5,597,845) 3,113,782 (5,597,845) Prepaid expenses and other assets 158,163 1,028,203 1,145,031 226,688 (1,163,509) Accounts payable (4,952,335) 18,562,202 16,816,386 (1,451,422) 50,808,461 Settlement of asset retirement obligation (836,778) (105,721) (193,036) (1,862,385) (2,741,380) Net Cash Provided by Operating Activities 55,733,207 55,390,975 63,641,506 198,170,459 196,976,729 Cash Flows From Investing Activities Payments for the Stronghold Acquisition — — 5,535,839 (18,511,170) (177,823,787) Payments for the Founders Acquisition (12,324,388) (49,902,757) — (62,227,145) — Payments to purchase oil and natural gas properties (557,323) (726,519) (352,012) (2,162,585) (1,563,703) Payments to develop oil and natural gas properties (39,563,282) (40,444,810) (45,556,105) (152,559,314) (129,332,155) Payments to acquire or improve fixed assets subject to depreciation (282,519) (183,904) (161,347) (492,317) (319,945) Sale of fixed assets subject to depreciation (1) — — 332,229 134,600 Proceeds from divestiture of oil and natural gas properties 1,500,000 — (1,366) 1,554,558 23,700 Proceeds from sale of Delaware properties (7,993) (384,225) — 7,600,699 — Proceeds from sale of New Mexico properties (420,745) 4,312,502 — 3,891,757 — Net Cash Used in Investing Activities (51,656,251) (87,329,713) (40,534,991) (222,573,288) (308,881,290) Cash Flows From Financing Activities Proceeds from revolving line of credit 46,000,000 94,500,000 44,000,000 225,000,000 636,000,000 Payments on revolving line of credit (49,000,000) (63,500,000) (64,000,000) (215,000,000) (511,000,000) Proceeds from issuance of common stock from warrant exercises — — 640,000 12,301,596 8,203,126 Payments for taxes withheld on vested restricted shares, net (225,788) (18,302) (256,715) (520,153) (521,199) Proceeds from notes payable 72,442 — 78,051 1,637,513 1,323,354 Payments on notes payable (488,776) (462,606) (455,802) (1,603,659) (1,409,884) Payment of deferred financing costs (52,222) — (129,026) (52,222) (18,891,528) Reduction of financing lease liabilities (224,809) (191,748) (161,064) (776,388) (495,098) Net Cash Provided by (Used in) Financing Activities (3,919,153) 30,327,344 (20,284,556) 20,986,687 113,208,771 Net Increase (Decrease) in Cash 157,803 (1,611,394) 2,821,959 (3,416,142) 1,304,210 Cash at Beginning of Period 138,581 1,749,975 890,567 3,712,526 2,408,316 Cash at End of Period $ 296,384 $ 138,581 $ 3,712,526 $ 296,384 $ 3,712,526 As of December 31, 2023 2022 ASSETS Current Assets Cash and cash equivalents $ 296,384 $ 3,712,526 Accounts receivable 38,965,002 42,448,719 Joint interest billing receivables, net 2,422,274 983,802 Derivative assets 6,215,374 4,669,162 Inventory 6,136,935 9,250,717 Prepaid expenses and other assets 1,874,850 2,101,538 Total Current Assets 55,910,819 63,166,464 Properties and Equipment Oil and natural gas properties, full cost method 1,663,548,249 1,463,838,595 Financing lease asset subject to depreciation 3,896,316 3,019,476 Fixed assets subject to depreciation 3,228,793 3,147,125 Total Properties and Equipment 1,670,673,358 1,470,005,196 Accumulated depreciation, depletion and amortization (377,252,572) (289,935,259) Net Properties and Equipment 1,293,420,786 1,180,069,937 Operating lease asset 2,499,592 1,735,013 Derivative assets 11,634,714 6,129,410 Deferred financing costs 13,030,481 17,898,973 Total Assets $ 1,376,496,392 $ 1,268,999,797 LIABILITIES AND STOCKHOLDERS’ EQUITY Current Liabilities Accounts payable $ 104,064,124 $ 111,398,268 Financing lease liability 956,254 709,653 Operating lease liability 568,176 398,362 Derivative liabilities 7,520,336 13,345,619 Notes payable 533,734 499,880 Deferred cash payment — 14,807,276 Asset retirement obligations 165,642 635,843 Total Current Liabilities 113,808,266 141,794,901 Non-current Liabilities Deferred income taxes 8,552,045 8,499,016 Revolving line of credit 425,000,000 415,000,000 Financing lease liability, less current portion 906,330 1,052,479 Operating lease liability, less current portion 2,054,041 1,473,897 Derivative liabilities 11,510,368 10,485,650 Asset retirement obligations 28,082,442 29,590,463 Total Liabilities 589,913,492 607,896,406 Commitments and contingencies Stockholders' Equity Preferred stock - $0.001 par value; 50,000,000 shares authorized; no shares issued or outstanding — — Common stock - $0.001 par value; 450,000,000 shares authorized; 196,837,001 shares and 175,530,212 shares issued and outstanding, respectively 196,837 175,530 Additional paid-in capital 795,834,675 775,241,114 Accumulated deficit (9,448,612) (114,313,253) Total Stockholders’ Equity 786,582,900 661,103,391 Total Liabilities and Stockholders' Equity $ 1,376,496,392 $ 1,268,999,797
Ring Energy, Inc. The Company defines “Adjusted Cash Flow from Operations” or “ACFFO” as Net Cash Provided by Operating Activities, per the Statements of Cash Flows, less the changes in operating assets and liabilities, including accounts receivable, inventory, prepaid expenses and other assets, accounts payable, and settlement of asset retirement obligation, which are subject to variation due to the nature of the Company’s operations. Accordingly, the Company believes this non-GAAP measure is useful to investors because it is used often in its industry and allows investors to compare this metric to other companies in its peer group as well as the E&P sector. “Leverage” or the “Leverage Ratio” is calculated under our existing senior revolving credit facility and means as of any date, the ratio of (i) our consolidated total debt as of such date to (ii) our Consolidated EBITDAX for the four consecutive fiscal quarters ending on or immediately prior to such date for which financial statements are required to have been delivered under our existing senior revolving credit facility; provided that for the purposes of the definition of ‘Leverage Ratio’, (a) for the fiscal quarter ended September 30, 2022, Consolidated EBITDAX is calculated by multiplying Consolidated EBITDAX for such fiscal quarter by four, (b) for the fiscal quarter ended December 31, 2022, Consolidated EBITDAX is calculated by multiplying Consolidated EBITDAX for the two fiscal quarter period ended on December 31, 2022 by two, (c) for the fiscal quarter ended March 31, 2023, Consolidated EBITDAX is calculated by multiplying Consolidated EBITDAX for the three fiscal quarter period ended on March 31, 2023 by four-thirds, and (d) for each fiscal quarter thereafter, Consolidated EBITDAX will be calculated by adding Consolidated EBITDAX for the four consecutive fiscal quarters ending on such date. The Company defines “Consolidated EBITDAX” in accordance with our existing senior revolving credit facility and it means for any period an amount equal to the sum of (i) consolidated net income for such period plus (ii) to the extent deducted in determining consolidated net income for such period, and without duplication, (A) consolidated interest expense, (B) income tax expense determined on a consolidated basis in accordance with GAAP, (C) depreciation, depletion and amortization determined on a consolidated basis in accordance with GAAP, (D) exploration expenses determined on a consolidated basis in accordance with GAAP, and (E) all other non-cash charges acceptable to our senior revolving credit facility administrative agent determined on a consolidated basis in accordance with GAAP, in each case for such period minus (iii) all noncash income added to consolidated net income for such period; provided that, for purposes of calculating compliance with the financial covenants set forth in our senior revolving credit facility, to the extent that during such period we shall have consummated an acquisition permitted by the senior revolving credit facility or any sale, transfer or other disposition of any person, business, property or assets permitted by the senior revolving credit facility, Consolidated EBITDAX will be calculated on a pro forma basis with respect to such person, business, property or assets so acquired or disposed of. Also set forth in our existing senior revolving credit facility is the maximum permitted Leverage Ratio of 3.00. PV-10 is a financial measure not prepared in accordance with GAAP that differs from a measure under GAAP known as “standardized measure of discounted future net cash flows” in that PV-10 is calculated without including future income taxes. Management believes that the presentation of the PV-10 value of the Company’s oil and natural gas properties is relevant and useful to investors because it presents the estimated discounted future net cash flows attributable to its estimated proved reserves independent of its income tax attributes, thereby isolating the intrinsic value of the estimated future cash flows attributable to its reserves. Management believes the use of a pre-tax measure provides greater comparability of assets when evaluating companies because the timing and quantification of future income taxes is dependent on company-specific factors, many of which are difficult to determine. For these reasons, management uses and believes that the industry generally uses the PV-10 measure in evaluating and comparing acquisition candidates and assessing the potential rate of return on investments in oil and natural gas properties. PV-10 does not necessarily represent the fair market value of oil and natural gas properties. PV-10 is not a measure of financial or operational performance under GAAP, nor should it be considered in isolation or as a substitute for the standardized measure of discounted future net cash flows as defined under GAAP. The Company defines “Return on Capital Employed” or “CROCE” as Adjusted Cash Flow from Operations divided by average debt and shareholder equity for the period. The Company defines All-In Cash Operating Costs, a non-GAAP financial measure, as “all in cash” costs including lease operating expenses, G&A costs excluding share-based compensation (“cash G&A”), interest expense, workovers and other operating expenses, production taxes, ad valorem taxes, and gathering/transportation costs. Management believes that this metric provides useful additional information to investors to assess the Company’s operating costs in comparison to its peers, which may vary from company to company. Non-GAAP Disclosure 32 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Certain financial information included in this Presentation are not measures of financial performance recognized by accounting principles generally accepted in the United States (“GAAP”). These non-GAAP financial measures are “Adjusted Net Income,” “Adjusted EBITDA,” “Adjusted Free Cash Flow” or “AFCF,” “Adjusted Cash Flow from Operations” or “ACFFO,” “Cash Return on Capital Employed” or “CROCE,” “Leverage Ratio” and “All-in Cash Operating Costs.” Management uses these non-GAAP financial measures in its analysis of performance. In addition, Adjusted EBITDA is a key metric used to determine the Company’s incentive compensation awards. These disclosures may not be viewed as a substitute for results determined in accordance with GAAP and are not necessarily comparable to non-GAAP performance measures which may be reported by other companies. “Adjusted Net Income” is calculated as net income (loss) minus the estimated after-tax impact of share-based compensation, ceiling test impairment, unrealized gains and losses on changes in the fair value of derivatives, and related transaction costs. Adjusted Net Income is presented because the timing and amount of these items cannot be reasonably estimated and affect the comparability of operating results from period to period, and current period to prior periods. The Company believes that the presentation of Adjusted Net Income provides useful information to investors as it is one of the metrics management uses to assess the Company’s ongoing operating and financial performance, and also is a useful metric for investors to compare our results with our peers. The Company defines “Adjusted EBITDA” as net income (loss) plus net interest expense, unrealized loss (gain) on change in fair value of derivatives, ceiling test impairment, income tax (benefit) expense, depreciation, depletion and amortization, asset retirement obligation accretion, transaction costs for executed acquisitions and divestitures (A&D), share-based compensation, loss (gain) on disposal of assets, and backing out the effect of other income. Company management believes Adjusted EBITDA is relevant and useful because it helps investors understand Ring’s operating performance and makes it easier to compare its results with those of other companies that have different financing, capital and tax structures. Adjusted EBITDA should not be considered in isolation from or as a substitute for net income, as an indication of operating performance or cash flows from operating activities or as a measure of liquidity. Adjusted EBITDA, as Ring calculates it, may not be comparable to Adjusted EBITDA measures reported by other companies. In addition, Adjusted EBITDA does not represent funds available for discretionary use. The Company defines “Adjusted Free Cash Flow” or “AFCF” as Net Cash Provided by Operating Activities less changes in operating assets and liabilities (as reflected on our statements of cash flows); plus transaction costs for executed acquisitions and divestitures; current tax expense (benefit); proceeds from divestitures of equipment for oil and natural gas properties; loss (gain) on disposal of assets; and less capital expenditures; bad debt expense; and other income. For this purpose, our definition of capital expenditures includes costs incurred related to oil and natural gas properties (such as drilling and infrastructure costs and the lease maintenance costs) but excludes acquisition costs of oil and gas properties from third parties that are not included in our capital expenditures guidance provided to investors. Our management believes that Adjusted Free Cash Flow is an important financial performance measure for use in evaluating the performance and efficiency of our current operating activities after the impact of accrued capital expenditures and net interest expense and without being impacted by items such as changes associated with working capital, which can vary substantially from one period to another. Other companies may use different definitions of Adjusted Free Cash Flow. The table below provides detail of PV-10 to the standardized measure of discounted future net cash flows as of December 31, 2023. ($ in 000’s) Present value of estimated future net revenues (PV-10) $ 1,647,031 Future income taxes, discounted at 10% 247,846 Standardized measure of discounted future net cash flows $ 1,399,185
Ring Energy, Inc. Non-GAAP Reconciliations 33 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Adjusted Net Income Adjusted EBITDA 1. Adjusted EBITDA Margin is Adj. EBITDA divided by oil, natural gas, and natural gas liquids revenue. (Unaudited for All Periods) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Total Per share - diluted Total Per share - diluted Total Per share - diluted Total Per share - diluted Total Per share - diluted Net Income (Loss) $ 50,896,479 $ 0.26 $ (7,539,222) $ (0.04) $ 14,492,669 $ 0.08 $104,864,641 $ 0.54 $138,635,025 $ 0.98 Share-based compensation 2,458,682 0.01 2,170,735 0.01 2,198,043 0.01 8,833,425 0.05 7,162,231 0.05 Unrealized loss (gain) on change in fair value of derivatives (32,505,544) (0.16) 33,871,957 0.17 5,398,617 0.03 (11,852,082) (0.07) (40,993,295) (0.29) Transaction costs - executed A&D 354,616 — (157,641) — 993,027 0.01 417,166 — 2,135,990 0.02 Tax impact on adjusted items (35,631) — (2,059,802) (0.01) (1,281,788) (0.01) (1,788,248) (0.01) 536,088 — Adjusted Net Income $ 21,168,602 $ 0.11 $ 26,286,027 $ 0.13 $ 21,800,568 $ 0.12 $100,474,902 $ 0.51 $107,476,039 $ 0.76 Diluted Weighted-Average Shares Outstanding 197,848,812 195,361,476 178,736,799 195,364,850 141,754,668 Adjusted Net Income per Diluted Share $ 0.11 $ 0.13 $ 0.12 $ 0.51 $ 0.76 (Unaudited for All Periods) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Net Income (Loss) $ 50,896,479 $ (7,539,222) $ 14,492,669 $104,864,641 $138,635,025 Interest expense, net 11,506,908 11,301,328 9,468,684 43,669,577 23,167,729 Unrealized loss (gain) on change in fair value of derivatives (32,505,544) 33,871,957 5,398,617 (11,852,082) (40,993,295) Income tax (benefit) expense 7,862,930 (3,411,336) 2,541,980 125,242 8,408,724 Depreciation, depletion and amortization 24,556,654 21,989,034 20,885,774 88,610,291 55,740,767 Asset retirement obligation accretion 351,786 354,175 365,747 1,425,686 983,432 Transaction costs - executed A&D 354,616 (157,641) 993,027 417,166 2,135,990 Share-based compensation 2,458,682 2,170,735 2,198,043 8,833,425 7,162,231 Loss (gain) on disposal of assets (44,981) — — 87,128 — Other income (72,725) — — (198,935) — Adjusted EBITDA $ 65,364,805 $ 58,579,030 $ 56,344,541 $235,982,139 $195,240,603 Adjusted EBITDA Margin 65 % 63 % 57 % 65 % 56 %1
Ring Energy, Inc. Non-GAAP Reconciliations (cont.) 34 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Leverage Ratio Adjusted Free Cash Flow (Unaudited for All Periods) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Net Cash Provided by Operating Activities $ 55,733,207 $ 55,390,975 $ 63,641,506 $ 198,170,459 $ 196,976,729 Adjustments - Condensed Statements of Cash Flows Changes in operating assets and liabilities (606,551) (6,843,290) (16,257,293) (1,180,748) (24,091,577) Transaction costs - executed A&D 354,616 (157,641) 993,027 417,166 2,135,990 Income tax expense (benefit) - current (192,048) 165,780 (36,736) 72,213 — Capital expenditures (38,817,080) (42,398,484) (42,618,754) (151,969,735) (140,051,159) Proceeds from divestiture of equipment for oil and natural gas properties — — (1,366) 54,558 23,700 Bad debt expense (92,142) (19,656) (242,247) (134,007) (242,247) Loss (gain) on disposal of assets (44,981) — — 87,128 — Other income (72,725) — — (198,935) — Adjusted Free Cash Flow $ 16,262,296 $ 6,137,684 $ 5,478,137 $ 45,318,099 $ 34,751,436 (Unaudited for All Periods) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Adjusted EBITDA $ 65,364,805 $ 58,579,030 $ 56,344,541 $ 235,982,139 $ 195,240,603 Net interest expense (excluding amortization of deferred financing costs) (10,285,429) (10,042,862) (8,246,284) (38,748,863) (20,461,708) Capital expenditures (38,817,080) (42,398,484) (42,618,754) (151,969,735) (140,051,159) Proceeds from divestiture of oil and natural gas properties — — (1,366) 54,558 23,700 Adjusted Free Cash Flow $ 16,262,296 $ 6,137,684 $ 5,478,137 $ 45,318,099 $ 34,751,436
Ring Energy, Inc. Non-GAAP Reconciliations (cont.) 35 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Adjusted Cash Flow from Operations (ACFFO) Cash Return on Capital Employed (CROCE) G&A Reconciliations PV-10 (Unaudited for All Periods) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Net Cash Provided by Operating Activities $ 55,733,207 $ 55,390,975 $ 63,641,506 $ 198,170,459 $ 196,976,729 Changes in operating assets and liabilities (606,551) (6,843,290) (16,257,293) (1,180,748) (24,091,577) Adjusted Cash Flow from Operations $ 55,126,656 $ 48,547,685 $ 47,384,213 $ 196,989,711 $ 172,885,152 (Unaudited for All Periods) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 General and administrative expense (G&A) $ 8,164,799 $ 7,083,574 $ 8,346,896 $ 29,188,755 $ 27,095,323 Shared-based compensation 2,458,682 2,170,735 2,198,043 8,833,425 7,162,231 G&A excluding share-based compensation 5,706,117 4,912,839 6,148,853 20,355,330 19,933,092 Transaction costs - executed A&D 354,616 (157,641) 993,027 417,166 2,135,990 G&A excluding share-based compensation and transaction costs $ 5,351,501 $ 5,070,480 $ 5,155,826 $ 19,938,164 $ 17,797,102 Oil (Bbl) Gas (Mcf) Natural Gas Liquids (Bbl) Net (Boe) PV-10(1) Balance, December 31, 2022 88,704,743 157,870,449 23,105,658 138,122,143 $ 2,773,656,500 Purchase of minerals in place 6,543,640 3,372,965 1,089,382 8,195,183 Extensions, discoveries and improved recovery 3,098,845 4,113,480 1,014,343 4,798,768 Sales of minerals in place (4,897,921) (2,674,955) (392,953) (5,736,700) Production (4,579,942) (6,339,158) (976,852) (6,613,320) Revisions of previous quantity estimates (6,728,088) (9,946,459) (621,014) (9,006,845) Balance, December 31, 2023 82,141,277 146,396,322 23,218,564 129,759,229 $ 1,647,031,127 As of and for the twelve months ended December 31, December 31, December 31, December 31, 2023 2022 2021 2021 Total long term debt (i.e. revolving line of credit) $425,000,000 $415,000,000 $290,000,000 $313,000,000 Total stockholders' equity $786,582,900 $661,103,391 $300,624,207 $294,765,813 Average debt $420,000,000 $352,500,000 $301,500,000 $339,750,000 Average stockholders' equity 723,843,146 480,863,799 297,695,010 409,137,873 Average debt and stockholders' equity 1,143,843,146 833,363,799 599,195,010 748,887,873 Net Cash Provided by Operating Activities $198,170,459 $196,976,729 $72,731,212 $72,159,255 Less change in WC (Working Capital) 1,180,748 24,091,577 3,236,824 2,418,446 Adjusted Cash Flows From Operations (ACFFO) $196,989,711 $172,885,152 $69,494,388 $69,740,809 CROCE (ACFFO)/(Average D+E) 17.2 % 20.7 % 11.6 % 9.3 %
Ring Energy, Inc. Non-GAAP Reconciliations (cont.) 36 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI All-In Cash Operating Costs . (Unaudited for All Periods) Three Months Ended Twelve Months Ended December 31, September 30, December 31, December 31, December 31, 2023 2023 2022 2023 2022 Lease operating expenses (including workovers) 18,732,082 18,015,348 17,411,645 70,158,227 47,695,351 G&A excluding share-based compensation 5,706,117 4,912,839 6,148,853 20,355,330 19,933,092 Net interest expense (excluding amortization of deferred financing costs) 10,285,429 10,042,862 8,246,284 38,748,863 20,461,704 Operating lease expense 175,090 138,220 113,138 541,801 363,908 Oil and natural gas production taxes 4,961,768 4,753,289 5,186,644 18,135,336 17,125,982 Ad valorem taxes 1,637,722 1,779,163 1,570,039 6,757,841 4,670,617 Gathering, transportation and processing costs 464,558 (4,530) (16,223) 457,573 1,830,024 All-in cash operating costs 41,962,766 39,637,191 38,660,380 155,154,971 112,080,678 Boe 1,784,490 1,610,857 1,642,715 6,613,321 4,512,610 All-in cash operating costs per Boe $ 23.52 $ 24.61 $ 23.53 $ 23.46 $ 24.84
Ring Energy, Inc. Experienced Management Team 37 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Shared Vision with a Track Record of Success • 40+ years of domestic & international oil & gas industry experience • Executive & board roles include CEO, President, COO, Region VP and public & private board directorships Paul D. McKinney Chairman & Chief Executive Officer Marinos Baghdati EVP of Operations Stephen D. Brooks EVP of Land, Legal, HR & Marketing Alexander Dyes EVP of Engineering & Corporate Strategy Travis Thomas EVP & Chief Financial Officer Hollie Lamb VP of NonOP Reservoir Engineering / O&G Marketing • 19+ years of oil & gas industry experience • Operational experience in drilling, completions and production including VP Operations, Operations manager, multiple engineering roles • 45+ years of oil & gas industry experience • Extensive career as landman including VP Land & Legal, VP HR VP Land and Land Manager • 17+ years of oil & gas industry experience • Multi-disciplined experience including VP A&D, VP Engineering, Director Strategy, multiple engineering & operational roles • 18+ years of oil & gas industry experience & accounting experience • High level financial experience including CAO, VP Finance, Controller, Treasurer • 20+ years of oil & gas industry experience • Previously Partner of HeLMS Oil & Gas, VP Engineering, Reservoir & Geologic Engineer
Ring Energy, Inc. Board of Directors 38 Value Focused Proven Strategy | March 7, 2024 | NYSE American: REI Accomplished and Diversified Experience • 40+ years of domestic & international oil & gas industry experience • Executive & board roles include CEO, President, COO, Region VP and public & private board directorships Paul D. McKinney Chairman & Chief Executive Officer • 43+ years of banking, capital markets, governance & financial experience • Executive and Board positions include CEO, President, multiple board chairs & directorships Anthony D. Petrelli Lead Independent Director • 14+ years of finance & capital markets experience • Extensive financial and capital markets acumen and experience including Managing Director and numerous Board Director positions Roy I. Ben-Dor Director • 45+ years of domestic & international oil & gas industry experience • Extensive executive roles including CEO, President & COO, and multiple public & private board chairs & directorships John A. Crum Independent Director • 24+ years of oil & gas industry, finance & capital markets experience • Wide range of operations, engineering, financial and capital markets roles and experience including Managing Director and numerous Board Director positions David S. Habachy Independent Director • 40+ years of experience across multiple industries • Executive positions in oil & gas, industrial equipment, and technology including CIO, Treasurer, Finance and Business Development Richard E. Harris Independent Director • 35+ years of domestic & international oil & gas industry experience • Executive & board roles include CFO, VP Accounting, Controller and public & private board directorships Thomas L. Mitchell Independent Director • 35+ years of banking, capital markets, governance & financial experience • Executive and Board positions including COO, director and Board Director positions Regina Roesener Independent Director • 50+ years of accounting, tax & finance experience • Wide range of financial acumen including positions as CFO, Partner in Charge and Board Director positions Clayton E. Woodrum Independent Director
www.ringenergy.com THANK YOU Company Contact Al Petrie (281) 975-2146 apetrie@ringenergy.com Wes Harris (281) 975-2146 wharris@ringenergy.com Analyst Coverage Alliance Global Partners (A.G.P.) Jeff Grampp (949) 296 4171 jgrampp@allianceg.com ROTH Capital Partners John M. White (949) 720-7115 jwhite@roth.com Truist Financial Neal Dingmann (713) 247-9000 neal.dingmann@truist.com Tuohy Bothers Investment Noel Parks (215) 913-7320 nparks@tuohybrothers.com Water Tower Research Jeff Robertson (469) 343-9962 jeff@watertowerresearch.com Ring Headquarters 1725 Hughes Landing Blvd Ste 900 The Woodlands, TX 77830 Phone: 281-397-3699
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Mar. 07, 2024 |
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8-K
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Mar. 07, 2024
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RING ENERGY, INC.
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NV
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1725 Hughes Landing Blvd
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Suite 900
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The Woodlands
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TX
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| X |
- DefinitionAddress Line 2 such as Street or Suite number
| Name: |
dei_EntityAddressAddressLine2 |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- Definition
+ References
+ Details
| Name: |
dei_EntityAddressCityOrTown |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionCode for the postal or zip code
| Name: |
dei_EntityAddressPostalZipCode |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionName of the state or province.
| Name: |
dei_EntityAddressStateOrProvince |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:stateOrProvinceItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionA unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityCentralIndexKey |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:centralIndexKeyItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionIndicate if registrant meets the emerging growth company criteria. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityEmergingGrowthCompany |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionCommission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.
| Name: |
dei_EntityFileNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:fileNumberItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTwo-character EDGAR code representing the state or country of incorporation.
| Name: |
dei_EntityIncorporationStateCountryCode |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarStateCountryItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityRegistrantName |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityTaxIdentificationNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:employerIdItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionLocal phone number for entity.
| Name: |
dei_LocalPhoneNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 13e
-Subsection 4c
| Name: |
dei_PreCommencementIssuerTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 14d
-Subsection 2b
| Name: |
dei_PreCommencementTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTitle of a 12(b) registered security. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b
| Name: |
dei_Security12bTitle |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:securityTitleItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionName of the Exchange on which a security is registered. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection d1-1
| Name: |
dei_SecurityExchangeName |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarExchangeCodeItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Section 14a
-Number 240
-Subsection 12
| Name: |
dei_SolicitingMaterial |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTrading symbol of an instrument as listed on an exchange.
| Name: |
dei_TradingSymbol |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:tradingSymbolItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Securities Act
-Number 230
-Section 425
| Name: |
dei_WrittenCommunications |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
Grafico Azioni Ring Energy (AMEX:REI)
Storico
Da Nov 2024 a Dic 2024
Grafico Azioni Ring Energy (AMEX:REI)
Storico
Da Dic 2023 a Dic 2024
