Open the filing on EDGARRING ENERGY RELEASES FIRST QUARTER 2026 RESULTS
The Woodlands, TX - May 6, 2026 - Ring Energy, Inc. (NYSE American: REI) (“Ring” or the “Company”) today reported operational and financial results for the first quarter of 2026.
First Quarter 2026 Highlights
- Sold 12,276 barrels of oil per day (“Bo/d”) and 19,351 barrels of oil equivalent per day (“Boe/d”) both of which were essentially at the mid-point of guidance;
- Reported a net loss of $220.6 million, or $(1.06) per diluted share, driven primarily by a $162.1 million non-cash ceiling test impairment and a $77.0 million unrealized mark-to-market derivative loss related to changes in forward commodity prices;
- Generated Adjusted Net Income of $7.4 million, or $0.04 per diluted share;
- Closed the sale of ~ 200 Boe/d of non-operated NWS assets for $4.5 million, valued at approximately 4.5 times estimated next twelve months cash flow;
- Incurred Lease Operating Expense (“LOE”) of $10.41 per Boe, 3% below the low end of guidance due to ongoing efforts to reduce costs;
- Invested $34.5 million in capital expenditures, accelerating targeted infrastructure investments to expand flexibility and unlock more capital efficient longer lateral inventory;
- Improved NWS spud‑to‑TD drilling time by ~15% versus the 2025 average;
- Generated net cash flow from operating activities of $25.9 million and remained cash flow positive for the 26 consecutive quarter; and
- Increased borrowings by $6 million to accelerate the capture of attractively priced opportunities while maintaining liquidity of $160.0 million as of March 31, 2026.
Management Commentary
Mr. Paul D. McKinney, Chairman of the Board and Chief Executive Officer, commented, “We successfully delivered on our sales guidance, handsomely beat on LOE, while investing ahead of our drilling campaign and extending our track record to 26 consecutive quarters of positive cash flow. Looking to the future, we believe the market has yet to recognize the potential impact of supply disruptions stemming from the Iranian Conflict and what that could mean for long term oil prices. Because we expect oil prices to remain elevated longer than the market currently implies, we made targeted adjustments late in the quarter to capture attractively priced opportunities that provide optionality and the potential to meaningfully expand our drilling inventory, improve capital efficiency and build long term stockholder value.”
Mr. McKinney concluded, “While we remained focused on operating within Adjusted Free Cash Flow during the first quarter of 2026, we temporarily paused debt reduction to invest in select opportunities which are compelling on a risk-adjusted basis. We are acting early to capture upside potential before sustained higher oil prices translate into higher costs and increased competition. We believe these actions should improve our production later in the year and into 2027; however, it is too early to reflect any increases in our production guidance at this time. Looking ahead, we expect to resume our focus on debt reduction during the remainder of 2026, as we balance growth with strengthening our balance sheet and increasing the Company’s size and scale.”
A non-GAAP financial measure; see the “Non-GAAP Financial Information” section in this release for more information including reconciliations to the most comparable GAAP measures.
The cash flow for the next twelve months (“NTM”) represents field level cash flow based on a strip price as of January 12, 2026.
Summary Results and Additional Key Items
| Q1 2026 | Q4 2025 | Q1 2026 to Q4 2025 % Change | Q1 2025 | Q1 2026 to Q1 2025 % Change |
|---|
| Average Daily Sales Volumes (Boe/d) | 19,351 | 20,508 | (6)% | 18,392 | 5% |
| Crude Oil (Bo/d) | 12,276 | 13,124 | (6)% | 12,074 | 2% |
| Net Sales (MBoe) | 1,741.6 | 1,886.8 | (8)% | 1,655.3 | 5% |
| Realized Price - All Products ($/Boe) | $42.30 | $35.45 | 19% | $47.78 | (11)% |
| Realized Price - Crude Oil ($/Bo) | $68.97 | $57.47 | 20% | $70.40 | (2)% |
| Revenues ($MM) | $73.7 | $66.9 | 10% | $79.1 | (7)% |
| Net Income (Loss) ($MM) | $(220.6) | $(12.8) | 1623% | $9.1 | (2524)% |
| Adjusted Net Income ($MM) | $7.4 | $3.6 | 106% | $10.7 | (31)% |
| Adjusted EBITDA ($MM) | $38.3 | $38.4 | - % | $46.4 | (17)% |
| Capital Expenditures ($MM) | $34.5 | $24.3 | 42% | $32.5 | 6% |
| Adjusted Free Cash Flow ($MM) | $0.2 | $5.7 | (96)% | $5.8 | (97)% |
(1) Adjusted Net Income, Adjusted EBITDA, and Adjusted Free Cash Flow are non-GAAP financial measures, which are described in more detail and reconciled to the most comparable GAAP measures, in the tables shown later in this release under “Non-GAAP Financial Information.” In addition, see section titled “Condensed Operating Data” for additional details concerning costs and expenses presented below.
Select Expenses and Other Items
| Q1 2026 | Q4 2025 | Q1 2026 to Q4 2025 % Change | Q1 2025 | Q1 2026 to Q1 2025 % Change |
|---|
| Lease operating expenses (“LOE”) ($MM) | $18.1 | $18.9 | (4)% | $19.7 | (8)% |
| Lease operating expenses ($/BOE) | $10.41 | $10.02 | 4% | $11.89 | (12)% |
| Depreciation, depletion and amortization ($MM) | $21.4 | $23.0 | (7)% | $22.6 | (5)% |
| Depreciation, depletion and amortization ($/BOE) | $12.29 | $12.19 | 1% | $13.66 | (10)% |
| General and administrative expenses (“G&A”) ($MM) | $7.4 | $8.0 | (8)% | $8.6 | (14)% |
| General and administrative expenses ($/BOE) | $4.27 | $4.26 | - % | $5.21 | (18)% |
| G&A excluding share-based compensation ($MM) | $5.9 | $6.6 | (11)% | $6.9 | (14)% |
| G&A excluding share-based compensation ($/BOE) | $3.40 | $3.47 | (2)% | $4.19 | (19)% |
| G&A excluding share-based compensation & transaction costs ($MM) | $5.9 | $6.5 | (9)% | $6.9 | (14)% |
| G&A excluding share-based compensation & transaction costs ($/BOE) | $3.40 | $3.46 | (2)% | $4.18 | (19)% |
| Interest expense ($MM) | $8.6 | $9.1 | (5)% | $9.5 | (9)% |
| Interest expense ($/BOE) | $4.94 | $4.83 | 2% | $5.74 | (14)% |
| Gain (loss) on derivative contracts ($MM) | $(82.2) | $17.5 | (570)% | $(0.9) | (9033)% |
| Realized gain (loss) on derivative contracts ($MM) | $(5.2) | $2.7 | (293)% | $(0.5) | (940)% |
| Unrealized gain (loss) on derivative contracts ($MM) | $(77.0) | $14.8 | (620)% | $(0.4) | (19150)% |
(1) A summary listing of the Company’s outstanding derivative positions as of May 5, 2026 is included in the tables shown later in this release. As of May 5, 2026, for the remainder (April through December) of 2026, the Company has approximately 2.6 million barrels of oil (approximately 72% of oil sales guidance midpoint) hedged at an average upside protection price of $73.27 and approximately 3.8 billion cubic feet of natural gas (approximately 73% of natural gas sales guidance midpoint) hedged at an average downside protection price of $3.78.
Balance Sheet and Liquidity
Total liquidity (defined as cash and cash equivalents plus borrowing base availability under the Company’s credit facility) at March 31, 2026 was approximately $160.0 million, consisting of $159.0 million of availability under our revolving credit facility, which included a reduction of $35 thousand for letters of credit, and $1.0 million in cash and cash equivalents. On March 31, 2026, the Company had $426 million in borrowings outstanding on its credit facility that has a current borrowing base of $585 million. This reflects an increase of $6 million from the balance of $420 million at December 31, 2025. The Company intends to resume debt reduction, dependent on market conditions, the timing and level of capital spending, and other considerations.
Ceiling Test Impairment
The Company accounts for its assets under the full cost method of accounting, which requires calculation of the limitation on capitalized costs (the full cost ceiling) each quarter. Due to a decrease in the twelve month average SEC commodity pricing over the past quarter, the Company recorded a non-cash impairment charge of $162.1 million in the first quarter of 2026. This non-cash charge had no net impact on cash flows.
Drilling and Completion Activity
In 1Q 2026 the Company continued execution of its development program across its core operated positions. In the Northwest Shelf (Yoakum County), Ring drilled and completed five one-mile horizontal wells, each with a working interest of approximately 91%. In addition, the Company in the Central Basin Platform (Crane County), completed one previously drilled one-mile horizontal DUC well, and drilled and completed one vertical well, with a 100% working interest.
The table below sets forth Ring’s drilling and completion activities in the first quarter of 2026:
| Quarter | Area | Wells Drilled | Wells Completed |
| 1Q 2026 | Northwest Shelf (Horizontal) | 5 | 5 |
| Central Basin Platform (Horizontal) | - | 1 |
| Central Basin Platform (Vertical) | 1 | 1 |
| Total | 6 | 7 |
(1) The horizontal well completed in the Central Basin Platform in the first quarter of 2026 is the completion of a previously drilled but uncompleted (“DUC”) well.
Remaining Quarters of 2026 Sales Volumes, Capital Investment and Operating Expense Guidance
The guidance in the table below represents the Company's current good faith estimate of the range of likely future results. Guidance could be affected by the factors discussed below in the "Safe Harbor Statement" section.
| Q2 | Q3 | Q4 |
|---|
| 2026 | 2026 | 2026 |
|---|
| Sales Volumes: | | | |
| Total Oil (Bo/d) | 12,450 - 13,450 | 12,750 - 13,750 | 12,800 - 13,800 |
| Midpoint (Bo/d) | 12,950 | 13,250 | 13,300 |
| Total (Boe/d) | 19,400 - 21,000 | 19,700 - 21,300 | 19,800 - 21,400 |
| Midpoint (Boe/d) | 20,200 | 20,500 | 20,600 |
| Oil (%) | 64% | 65% | 65% |
| NGLs (%) | 20% | 20% | 20% |
| Gas (%) | 16% | 15% | 15% |
| Capital Program: | | | |
| Capital spending (millions) | $28 - $36 | $27 - $35 | $17 - $25 |
| Midpoint (millions) | $32 | $31 | $21 |
| New Hz wells drilled | 5 - 7 | 5 - 7 | 3 - 5 |
| New Vertical wells drilled | 1 - 2 | 1 - 2 | 1 |
| Wells completed and online | 6 - 9 | 6 - 9 | 4 - 6 |
| Operating Expenses: | | | |
| LOE (per Boe) | $10.05 - $11.05 | $10.00 - $11.00 | $10.00 - $11.00 |
| Midpoint (per Boe) | $10.55 | $10.50 | $10.50 |
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 acreage; and non-operated drilling, completion, capital workovers, and facility improvements.
Conference Call Information
Ring will hold a conference call on Thursday, May 7, 2026 at 11:00 a.m. ET (10 a.m. CT) to discuss its 1Q 2026 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 1Q 2026 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
Forward-looking statements notice
This release contains 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. Forward-looking statements involve a wide variety of risks and uncertainties, and include, without limitation, statements with respect to the Company’s strategy and prospects. The forward-looking statements include statements about the expected future reserves, production, financial position, business strategy, revenues, earnings, costs, capital expenditures and debt levels of the Company, and plans and objectives of management for future operations. Forward-looking statements also include assumptions and projections for remaining quarters of 2026 guidance for sales volumes, oil, NGL and natural gas mix as a percentage of total sales, capital expenditures, operating expenses and the projected impacts thereon. Forward-looking statements are based on current expectations and assumptions and analyses made by Ring and its management in light of their experience and perception of historical trends, current conditions and expected future developments, as well as other factors appropriate under the circumstances. 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; the impact of worldwide political, military and armed conflict (including the impact of the ongoing conflict with Iran and the closure of the Strait of Hormuz); adverse weather conditions that may negatively impact development or production activities particularly in the winter; 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; changes in U.S. energy, environmental, monetary, tax and trade policies, including with respect to tariffs or other trade barriers, and any resulting trade tensions; cost and availability of transportation and storage capacity as a result of oversupply, government regulation or other factors; 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, 2025, and its other SEC filings. 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
Condensed Statements of Operations
(Unaudited)
| Three Months Ended |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Oil, Natural Gas, and Natural Gas Liquids Revenues | $73,671,664 | | $66,882,770 | | $79,091,207 | |
| Costs and Operating Expenses | | | |
| Lease operating expenses | 18,122,344 | | 18,911,801 | | 19,677,552 | |
| Gathering, transportation and processing costs | 117,049 | | 121,097 | | 203,612 | |
| Ad valorem taxes | 2,202,537 | | 2,279,266 | | 1,532,108 | |
| Oil and natural gas production taxes | 3,553,891 | | 3,224,183 | | 3,584,455 | |
| Depreciation, depletion and amortization | 21,405,948 | | 23,002,908 | | 22,615,983 | |
| Ceiling test impairment | 162,086,257 | | 35,913,116 | | - | |
| Asset retirement obligation accretion | 395,496 | | 390,892 | | 326,549 | |
| Operating lease expense | 175,091 | | 175,090 | | 175,091 | |
| General and administrative expense | 7,438,778 | | 8,030,310 | | 8,619,976 | |
| Total Costs and Operating Expenses | 215,497,391 | | 92,048,663 | | 56,735,326 | |
| Income (Loss) from Operations | (141,825,727) | | (25,165,893) | | 22,355,881 | |
| Other Income (Expense) | | | |
| Interest income | 70,529 | | 56,910 | | 90,058 | |
| Interest (expense) | (8,599,609) | | (9,122,419) | | (9,498,786) | |
| Gain (loss) on derivative contracts | (82,230,925) | | 17,495,270 | | (928,790) | |
| Gain (loss) on disposal of assets | - | | 60,855 | | 124,610 | |
| Other income | 5,837 | | 29,582 | | 8,942 | |
| Net Other Income (Expense) | (90,754,168) | | 8,520,198 | | (10,203,966) | |
| Income (Loss) Before Benefit from (Provision for) Income Taxes | (232,579,895) | | (16,645,695) | | 12,151,915 | |
| Benefit from (Provision for) Income Taxes | 11,988,413 | | 3,800,401 | | (3,041,177) | |
| Net Income (Loss) | $(220,591,482) | | $(12,845,294) | | $9,110,738 | |
| Basic Earnings (Loss) per Share | $(1.06) | | $(0.06) | | $0.05 | |
| Diluted Earnings (Loss) per Share | $(1.06) | | $(0.06) | | $0.05 | |
| Basic Weighted-Average Shares Outstanding | | 208,558,546 | | 207,233,067 | | 199,314,182 |
| Diluted Weighted-Average Shares Outstanding | | 208,558,546 | | 207,233,067 | | 201,072,594 |
Condensed Operating Data
(Unaudited)
| Three Months Ended |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Net sales volumes: | | | |
| Oil (Bbls) | | 1,104,823 | | 1,207,425 | | 1,086,694 |
| Natural gas (Mcf) | | 1,689,512 | | 1,808,355 | | 1,615,196 |
| Natural gas liquids (Bbls) | | 355,173 | | 377,937 | | 299,366 |
| Total oil, natural gas and natural gas liquids (Boe) | | 1,741,581 | | 1,886,755 | | 1,655,259 |
| % Oil | 64% | | 64% | | 66% | |
| % Natural Gas | 16% | | 16% | | 16% | |
| % Natural Gas Liquids | 20% | | 20% | | 18% | |
| Average daily sales volumes: | | | |
| Oil (Bbls/d) | | 12,276 | | 13,124 | | 12,074 |
| Natural gas (Mcf/d) | | 18,772 | | 19,656 | | 17,947 |
| Natural gas liquids (Bbls/d) | | 3,946 | | 4,108 | | 3,326 |
| Average daily equivalent sales (Boe/d) | | 19,351 | | 20,508 | | 18,392 |
| Average realized sales prices: | | | |
| Oil ($/Bbl) | $68.97 | | $57.47 | | $70.40 | |
| Natural gas ($/Mcf) | (2.54) | | (2.49) | | (0.19) | |
| Natural gas liquids ($/Bbls) | 4.96 | | 5.29 | | 9.65 | |
| Barrel of oil equivalent ($/Boe) | $42.30 | | $35.45 | | $47.78 | |
| Average costs and expenses per Boe ($/Boe): | | | |
| Lease operating expenses | $10.41 | | $10.02 | | $11.89 | |
| Gathering, transportation and processing costs | 0.07 | | 0.06 | | 0.12 | |
| Ad valorem taxes | 1.26 | | 1.21 | | 0.93 | |
| Oil and natural gas production taxes | 2.04 | | 1.71 | | 2.17 | |
| Depreciation, depletion and amortization | 12.29 | | 12.19 | | 13.66 | |
| Ceiling test impairment | 93.07 | | 19.03 | | - | |
| Asset retirement obligation accretion | 0.23 | | 0.21 | | 0.20 | |
| Operating lease expense | 0.10 | | 0.09 | | 0.11 | |
| G&A (including share-based compensation) | 4.27 | | 4.26 | | 5.21 | |
| G&A (excluding share-based compensation) | 3.40 | | 3.47 | | 4.19 | |
| G&A (excluding share-based compensation and transaction costs) | 3.40 | | 3.46 | | 4.18 | |
(1) 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.
Condensed Balance Sheets
(Unaudited)
| As of |
|---|
| March 31, 2026 | December 31, 2025 |
|---|
| ASSETS | | |
| Current Assets | | |
| Cash and cash equivalents | $1,040,636 | $902,913 |
| Accounts receivable | 45,731,039 | 30,938,908 |
| Joint interest billing receivables, net | 901,472 | 1,623,991 |
| Derivative assets | 4,016,834 | 21,468,134 |
| Inventory | 6,148,963 | 5,312,715 |
| Prepaid expenses and other assets | 1,426,496 | 1,822,751 |
| Total Current Assets | 59,265,440 | 62,069,412 |
| Properties and Equipment | | |
| Oil and natural gas properties, full cost method | 1,761,765,033 | 1,891,510,431 |
| Financing lease asset subject to depreciation | 3,676,412 | 3,633,586 |
| Fixed assets subject to depreciation | 3,504,788 | 3,504,788 |
| Total Properties and Equipment | 1,768,946,233 | 1,898,648,805 |
| Accumulated depreciation, depletion and amortization | (590,499,944) | (569,180,901) |
| Net Properties and Equipment | 1,178,446,289 | 1,329,467,904 |
| Operating lease asset | 1,125,245 | 1,285,159 |
| Derivative assets | 7,199,724 | 9,739,430 |
| Deferred financing costs | 8,678,656 | 9,337,344 |
| Total Assets | $1,254,715,354 | $1,411,899,249 |
| LIABILITIES AND STOCKHOLDERS’ EQUITY | | |
| Current Liabilities | | |
| Accounts payable | $102,616,433 | $90,258,731 |
| Income tax liability | 535,318 | 356,436 |
| Financing lease liability | 686,697 | 730,564 |
| Operating lease liability | 539,464 | 586,614 |
| Derivative liabilities | 43,082,871 | 841,193 |
| Notes payable | - | 505,752 |
| Asset retirement obligations | 397,413 | 418,526 |
| Total Current Liabilities | 147,858,196 | 93,697,816 |
| Non-current Liabilities | | |
| Deferred income taxes | 10,214,701 | 22,298,701 |
| Revolving line of credit | 426,000,000 | 420,000,000 |
| Financing lease liability, less current portion | 487,110 | 593,146 |
| Operating lease liability, less current portion | 695,226 | 819,223 |
| Derivative liabilities | 17,234,923 | 2,512,692 |
| Asset retirement obligations | 30,247,250 | 29,972,429 |
| Total Liabilities | 632,737,406 | 569,894,007 |
| 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; 209,395,110 shares and 207,656,929 shares issued and outstanding, respectively | 209,395 | 207,657 |
| Additional paid-in capital | 813,340,036 | 812,777,586 |
| Retained earnings (Accumulated deficit) | (191,571,483) | 29,019,999 |
| Total Stockholders’ Equity | 621,977,948 | 842,005,242 |
| Total Liabilities and Stockholders' Equity | $1,254,715,354 | $1,411,899,249 |
Condensed Statements of Cash Flows
(Unaudited)
| Three Months Ended |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Cash Flows From Operating Activities | | | |
| Net income (loss) | $(220,591,482) | | $(12,845,294) | | $9,110,738 | |
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | | |
| Depreciation, depletion and amortization | 21,405,948 | | 23,002,908 | | 22,615,983 | |
| Ceiling test impairment | 162,086,257 | | 35,913,116 | | - | |
| Asset retirement obligation accretion | 395,496 | | 390,892 | | 326,549 | |
| Amortization of deferred financing costs | 694,148 | | 691,228 | | 1,238,493 | |
| Share-based compensation | 1,524,808 | | 1,474,560 | | 1,690,958 | |
| Credit loss expense | - | | - | | 17,917 | |
| (Gain) loss on disposal of assets | - | | (60,855) | | (124,610) | |
| Deferred income tax expense (benefit) | (12,242,582) | | (3,650,179) | | 2,805,346 | |
| Excess tax expense (benefit) related to share-based compensation | 158,582 | | (201,533) | | 99,437 | |
| (Gain) loss on derivative contracts | 82,230,925 | | (17,495,270) | | 928,790 | |
| Cash received (paid) for derivative settlements, net | (5,276,011) | | 2,741,821 | | (553,594) | |
| Changes in operating assets and liabilities: | | | |
| Accounts receivable | (14,069,612) | | 2,153,443 | | (564,158) | |
| Inventory | (836,248) | | (327,355) | | 747,064 | |
| Prepaid expenses and other assets | 396,255 | | 454,986 | | 624,812 | |
| Accounts payable | 10,221,636 | | 12,513,783 | | (10,385,137) | |
| Settlement of asset retirement obligation | (203,419) | | (67,428) | | (207,580) | |
| Net Cash Provided by Operating Activities | 25,894,701 | | 44,688,823 | | 28,371,008 | |
| Cash Flows From Investing Activities | | | |
| Payments for the Lime Rock Acquisition | - | | (9,293,884) | | (70,859,769) | |
| Payments to purchase oil and natural gas properties | (2,781,731) | | (1,016,517) | | (647,106) | |
| Payments to develop oil and natural gas properties | (32,506,820) | | (24,955,052) | | (31,083,507) | |
| Payments to acquire or improve fixed assets subject to depreciation | - | | (4,402) | | (34,275) | |
| Proceeds from sale of fixed assets subject to depreciation | - | | - | | 17,360 | |
| Proceeds from divestiture of oil and natural gas properties | 4,266,479 | | - | | - | |
| Net Cash Used in Investing Activities | (31,022,072) | | (35,269,855) | | (102,607,297) | |
| Cash Flows From Financing Activities | | | |
| Proceeds from revolving line of credit | 48,000,000 | | 30,500,000 | | 114,000,000 | |
| Payments on revolving line of credit | (42,000,000) | | (38,500,000) | | (39,000,000) | |
| Payments for taxes withheld on vested restricted shares, net | (965) | | (228,359) | | (896,431) | |
| Payments on notes payable | (505,752) | | (496,077) | | (496,397) | |
| Payment of deferred financing costs | (35,460) | | 66,871 | | - | |
| Reduction of financing lease liabilities | (192,729) | | (145,397) | | (136,427) | |
| Net Cash Provided by (Used in) Financing Activities | 5,265,094 | | (8,802,962) | | 73,470,745 | |
| Net Increase (Decrease) in Cash | 137,723 | | 616,006 | | (765,544) | |
| Cash at Beginning of Period | 902,913 | | 286,907 | | 1,866,395 | |
| Cash at End of Period | $1,040,636 | | $902,913 | | $1,100,851 | |
Financial Commodity Derivative Positions
As of May 5, 2026
The following tables reflect the details of current derivative contracts as of May 5, 2026 (quantities are in barrels (Bbl) for the oil derivative contracts and in million British thermal units (MMBtu) for the natural gas derivative contracts):
| Oil Hedges (WTI) | Q2 2026 | Q3 2026 | Q4 2026 | Q1 2027 | Q2 2027 | Q3 2027 | Q4 2027 | Q1 2028 |
| Swaps: | | | | | | | | |
| Hedged volume (Bbl) | 622,601 | 263,400 | 529,000 | 509,500 | 492,000 | 432,000 | 412,963 | - |
| Weighted average swap price | $66.43 | $61.77 | $65.34 | $62.82 | $60.45 | $61.80 | $57.59 | $ - |
| Two-way collars: | | | | | | | | |
| Hedged volume (Bbl) | 273,000 | 563,685 | 368,000 | - | - | - | - | 400,080 |
| Weighted average put price | $55.00 | $60.82 | $65.00 | $ - | $ - | $ - | $ - | $55.45 |
| Weighted average call price | $65.65 | $76.19 | $105.65 | $ - | $ - | $ - | $ - | $65.45 |
| Swaps: WTI NYMEX Rolls | | | | | | | | |
| Hedged volume (BBL) | 819,000 | 828,000 | - | - | - | - | - | - |
| Weighted average swap price | $5.30 | $5.98 | $ - | $ - | $ - | $ - | $ - | $ - |
| Gas Hedges (Henry Hub) | Q2 2026 | Q3 2026 | Q4 2026 | Q1 2027 | Q2 2027 | Q3 2027 | Q4 2027 | Q1 2028 |
| NYMEX Swaps: | | | | | | | | |
| Hedged volume (MMBtu) | 1,165,628 | 600,016 | 1,072,305 | 439,678 | 423,035 | 1,079,906 | 1,046,151 | 1,012,567 |
| Weighted average swap price | $3.82 | $4.19 | $3.99 | $4.02 | $4.02 | $3.86 | $4.02 | $3.77 |
| Two-way collars: | | | | | | | | |
| Hedged volume (MMBtu) | 139,000 | 648,728 | 128,000 | 717,000 | 694,000 | - | - | - |
| Weighted average put price | $3.50 | $3.10 | $3.50 | $3.99 | $3.00 | $ - | $ - | $ - |
| Weighted average call price | $5.42 | $4.24 | $5.42 | $5.21 | $4.32 | $ - | $ - | $ - |
| Gas Hedges (Henry Hub) | Q2 2028 | Q3 2028 | Q4 2028 | Q1 2029 | Q2 2029 | Q3 2029 | Q4 2029 |
| NYMEX Swaps: | | | | | | | |
| Hedged volume (MMBtu) | 984,322 | 956,865 | 931,539 | 908,117 | 886,933 | 866,585 | 846,134 |
| Weighted average swap price | $3.77 | $3.77 | $3.77 | $3.67 | $3.67 | $3.67 | $3.67 |
| Gas Hedges (basis differential) | Q2 2026 | Q3 2026 | Q4 2026 | Q1 2027 | Q2 2027 | Q3 2027 | Q4 2027 | Q1 2028 |
| Waha basis swaps: | | | | | | | | |
| Hedged volume (MMBtu) | - | - | 169,880 | 196,372 | 480,325 | 464,360 | 449,846 | 435,403 |
| Weighted average spread price | $ - | $ - | $1.32 | $0.78 | $0.78 | $0.78 | $0.78 | $0.68 |
| El Paso Permian Basin basis swaps: | | | | | | | | |
| Hedged volume (MMBtu) | - | - | 225,184 | 960,307 | 636,710 | 615,547 | 596,306 | 577,163 |
| Weighted average spread price | $ - | $ - | $1.35 | $0.72 | $0.67 | $0.67 | $0.67 | $0.60 |
(1) The gas basis swap hedges are calculated as the Henry Hub natural gas price less the fixed amount specified as the weighted average spread price above.
Non-GAAP Financial 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,” “All-In Cash Operating Costs,” and “Cash Operating Margin.” Management uses these non-GAAP financial measures in its analysis of performance. 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 transaction costs for acquisitions and divestitures (“A&D”). 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 the Company’s results with its peers.
| (Unaudited for All Periods) |
|---|
| Three Months Ended |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Total | Per share - diluted | Total | Per share - diluted | Total | Per share - diluted |
|---|
| Net income (loss) | $(220,591,482) | $(1.06) | | $(12,845,294) | $(0.06) | | $9,110,738 | $0.05 | |
| Share-based compensation | 1,524,808 | 0.01 | | 1,474,560 | 0.01 | | 1,690,958 | 0.01 | |
| Ceiling test impairment | 162,086,257 | 0.78 | | 35,913,116 | 0.17 | | - | - | |
| Unrealized loss (gain) on change in fair value of derivatives | 76,954,914 | 0.37 | | (14,753,449) | (0.07) | | 375,196 | - | |
| Transaction costs - A&D | - | - | | 25,000 | - | | 1,776 | - | |
| Tax impact on adjusted items | (12,557,544) | (0.06) | | (6,213,517) | (0.03) | | (500,646) | (0.01) | |
| Adjusted Net Income | $7,416,953 | $0.04 | | $3,600,416 | $0.02 | | $10,678,022 | $0.05 | |
| Diluted Weighted-Average Shares Outstanding | 208,558,546 | | 207,233,067 | | 201,072,594 | |
| Adjusted Net Income per Diluted Share | $0.04 | | $0.02 | | $0.05 | |
Reconciliation of Net income (loss) to Adjusted EBITDA
The Company defines “Adjusted EBITDA” as net income (loss) plus net interest expense (including interest income and 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 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 |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Net income (loss) | $(220,591,482) | | $(12,845,294) | | $9,110,738 | |
| Interest expense, net | 8,529,080 | | 9,065,509 | | 9,408,728 | |
| Unrealized loss (gain) on change in fair value of derivatives | 76,954,914 | | (14,753,449) | | 375,196 | |
| Ceiling test impairment | 162,086,257 | | 35,913,116 | | - | |
| Income tax (benefit) expense | (11,988,413) | | (3,800,401) | | 3,041,177 | |
| Depreciation, depletion and amortization | 21,405,948 | | 23,002,908 | | 22,615,983 | |
| Asset retirement obligation accretion | 395,496 | | 390,892 | | 326,549 | |
| Transaction costs - A&D | - | | 25,000 | | 1,776 | |
| Share-based compensation | 1,524,808 | | 1,474,560 | | 1,690,958 | |
| Loss (gain) on disposal of assets | - | | (60,855) | | (124,610) | |
| Other income | (5,837) | | (29,582) | | (8,942) | |
| Adjusted EBITDA | $38,310,771 | | $38,382,404 | | $46,437,553 | |
| Adjusted EBITDA Margin | 52% | | 57% | | 59% | |
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 (as reflected on the Company’s Condensed Statements of Cash Flows) less changes in operating assets and liabilities, and plus transaction costs for acquisitions and divestitures (“A&D”), current income tax expense (benefit), proceeds from divestitures of equipment for oil and natural gas properties, loss (gain) on disposal of assets, and less capital expenditures, credit loss expense, and other income. For this purpose, the Company’s 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 the Company’s capital expenditures guidance provided to investors. Management believes that Adjusted Free Cash Flow is an important financial performance measure for use in evaluating the performance and efficiency of the Company’s current operating activities after the impact of capital expenditures and net interest expense (including interest income and expense, excluding amortization of deferred financing costs) 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 |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Net Cash Provided by Operating Activities | $25,894,701 | | $44,688,823 | | $28,371,008 | |
| Adjustments - Condensed Statements of Cash Flows | | | |
| Changes in operating assets and liabilities | 4,491,388 | | (14,727,429) | | 9,784,999 | |
| Transaction costs - A&D | - | | 25,000 | | 1,776 | |
| Income tax expense (benefit) - current | 95,587 | | 51,311 | | 136,394 | |
| Capital expenditures | (34,505,509) | | (24,343,200) | | (32,451,531) | |
| Proceeds from divestiture of oil and natural gas properties | 4,266,479 | | - | | - | |
| Credit loss expense | - | | - | | (17,917) | |
| Other income | (5,837) | | (29,582) | | (8,942) | |
| Adjusted Free Cash Flow | $236,809 | | $5,664,923 | | $5,815,787 | |
| (Unaudited for All Periods) |
|---|
| Three Months Ended |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Adjusted EBITDA | $38,310,771 | | $38,382,404 | | $46,437,553 | |
| Net interest expense (excluding amortization of deferred financing costs) | (7,834,932) | | (8,374,281) | | (8,170,235) | |
| Capital expenditures | (34,505,509) | | (24,343,200) | | (32,451,531) | |
| Proceeds from divestiture of oil and natural gas properties | 4,266,479 | | - | | - | |
| Adjusted Free Cash Flow | $236,809 | | $5,664,923 | | $5,815,787 | |
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, as reflected in the Company’s Condensed Statements of Cash Flows, less the changes in operating assets and liabilities, which includes accounts receivable, inventory, prepaid expenses and other assets, accounts payable, and settlement of asset retirement obligations, which are subject to variation due to the nature of the Company’s operations. Accordingly, the Company believes this financial performance 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 |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Net Cash Provided by Operating Activities | $25,894,701 | | $44,688,823 | | $28,371,008 | |
| Changes in operating assets and liabilities | 4,491,388 | | (14,727,429) | | 9,784,999 | |
| Adjusted Cash Flow from Operations | $30,386,089 | | $29,961,394 | | $38,156,007 | |
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 for acquisitions and divestitures (A&D).
| (Unaudited for All Periods) |
|---|
| Three Months Ended |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| General and administrative expense (G&A) | $7,438,778 | | $8,030,310 | | $8,619,976 | |
| Shared-based compensation | 1,524,808 | | 1,474,560 | | 1,690,958 | |
| G&A excluding share-based compensation | $5,913,970 | | $6,555,750 | | $6,929,018 | |
| Transaction costs - A&D | - | | 25,000 | | 1,776 | |
| G&A excluding share-based compensation and transaction costs | $5,913,970 | | $6,530,750 | | $6,927,242 | |
Calculation of Leverage Ratio
“Leverage” or the “Leverage Ratio” is calculated pursuant to the Company’s existing senior revolving credit facility and means as of any date, the ratio of (i) Consolidated Total Debt as of such date to (ii) 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 the credit facility.
The Company defines “Consolidated Total Debt” in accordance with its existing senior revolving credit facility and means, as of any date, all Indebtedness of the Company on a consolidated basis as of such date, but excluding hedging obligations.
The Company defines “Indebtedness” in accordance with its existing senior revolving credit facility and generally means (i) all obligations of the Company for borrowed money, (ii) all obligations of the Company evidenced by notes or other similar instruments, (iii) all obligations of the Company in respect of the deferred purchase price of property or services, (iv) all obligations of the Company under any conditional sale relating to property acquired the Company, (v) all capital lease obligations of the Company, (vi) all obligations, contingent or otherwise, of the Company in respect of letters of credit or similar extensions of credit, (vii) all guarantees of the Company of the type of Indebtedness described in clauses (i) through (vi) above, (viii) all Indebtedness of a third party secured by any lien on property owned by the Company, whether or not such Indebtedness has been assumed by the Company, (ix) all off-balance sheet liabilities, (x) all hedging obligations and (xi) the undischarged balance of any production payment created by the Company or for the creation of which the Company directly or indirectly received payment.
The Company defines “Consolidated EBITDAX” in accordance with its existing senior revolving credit facility and 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 (loss) for such period, and without duplication, (A) consolidated interest expense, (B) income tax expense (benefit) determined on a consolidated basis, (C) depreciation, depletion and amortization determined on a consolidated basis, (D) exploration expenses determined on a consolidated basis, and (E) all other non-cash charges reasonably acceptable to the administrative agent, 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 under the credit facility, to the extent that during such period the Company has consummated an acquisition permitted by the credit facility or any sale, transfer or other disposition of any property or assets permitted by the credit facility, Consolidated EBITDAX will be calculated on a pro forma basis with respect to the property or assets acquired or disposed of.
The maximum permitted Leverage Ratio under the senior revolving credit facility is 3.00. The following tables show the leverage ratio calculations for the quarters ended March 31, 2026 and March 31, 2025.
| (Unaudited) |
|---|
| Three Months Ended | |
|---|
| June 30, | September 30, | December 31, | March 31, | Last Four Quarters |
|---|
| 2025 | 2025 | 2025 | 2026 | |
|---|
| Consolidated EBITDAX Calculation: | | | | | |
| Net Income (Loss) | $20,634,887 | | $(51,631,530) | | $(12,845,294) | | $(220,591,482) | | $(264,433,419) |
| Plus: Consolidated interest expense | 11,687,746 | | 9,978,067 | | 9,065,509 | | 8,529,080 | | 39,260,402 |
| Plus: Income tax provision (benefit) | 6,107,425 | | (12,800,947) | | (3,800,401) | | (11,988,413) | | (22,482,336) |
| Plus: Depreciation, depletion and amortization | 25,569,914 | | 25,225,345 | | 23,002,908 | | 21,405,948 | | 95,204,115 |
| Plus: non-cash charges reasonably acceptable to Administrative Agent | (12,236,121) | | 77,063,418 | | 23,025,119 | | 240,961,475 | | 328,813,891 |
| Consolidated EBITDAX | $51,763,851 | | $47,834,353 | | $38,447,841 | | $38,316,608 | | $176,362,653 |
| Plus: Pro Forma Acquired Consolidated EBITDAX | - | | - | | - | | - | | - |
| Less: Pro Forma Divested Consolidated EBITDAX | - | | - | | - | | - | | - |
| Pro Forma Consolidated EBITDAX | $51,763,851 | | $47,834,353 | | $38,447,841 | | $38,316,608 | | $176,362,653 |
| Non-cash charges reasonably acceptable to Administrative Agent: | | | | | |
| Asset retirement obligation accretion | $382,251 | | $390,563 | | $390,892 | | $395,496 | | |
| Unrealized loss (gain) on derivative assets | (13,970,211) | | 2,141,925 | | (14,753,449) | | 76,954,914 | | |
| Ceiling test impairment | - | | 72,912,330 | | 35,913,116 | | 162,086,257 | | |
| Share-based compensation | 1,351,839 | | 1,618,600 | | 1,474,560 | | 1,524,808 | | |
| Total non-cash charges reasonably acceptable to Administrative Agent | $(12,236,121) | | $77,063,418 | | $23,025,119 | | $240,961,475 | | |
| As of | | | | |
| March 31, | Corresponding | | | |
| | 2026 | Leverage Ratio | | | |
| Leverage Ratio Covenant: | | | | | |
| Revolving line of credit | $426,000,000 | | | 2.42 | | | |
| Notes payable | - | | - | | | | |
| Deferred payment | - | | - | | | | |
| Capital lease obligations | $1,173,807 | | - | | | | |
| Consolidated Total Debt | $427,173,807 | | 2.42 | | | | |
| Pro Forma Consolidated EBITDAX | 176,362,653 | | | | | |
| Leverage Ratio | 2.42 | | | | | |
| Maximum Allowed | ≤ 3.00x | | | | |
| (Unaudited) |
|---|
| Three Months Ended | |
|---|
| June 30, | September 30, | December 31, | March 31, | Last Four Quarters |
|---|
| 2024 | 2024 | 2024 | 2025 | |
|---|
| Consolidated EBITDAX Calculation: | | | | | |
| Net Income (Loss) | $22,418,994 | | $33,878,424 | | $5,657,519 | | $9,110,738 | | $71,065,675 |
| Plus: Consolidated interest expense | 10,801,194 | | 10,610,539 | | 9,987,731 | | 9,408,728 | | 40,808,192 |
| Plus: Income tax provision (benefit) | 6,820,485 | | 10,087,954 | | 1,803,629 | | 3,041,177 | | 21,753,245 |
| Plus: Depreciation, depletion and amortization | 24,699,421 | | 25,662,123 | | 24,548,849 | | 22,615,983 | | 97,526,376 |
| Plus: non-cash charges acceptable to Administrative Agent | 1,664,064 | | (26,228,108) | | 8,994,957 | | 2,392,703 | | (13,176,384) |
| Consolidated EBITDAX | $66,404,158 | | $54,010,932 | | $50,992,685 | | $46,569,329 | | $217,977,104 |
| Plus: Pro Forma Acquired Consolidated EBITDAX | 10,329,116 | | 7,838,163 | | 5,244,078 | | 7,392,359 | | 30,803,716 |
| Less: Pro Forma Divested Consolidated EBITDAX | (469,376) | | (600,460) | | 77,819 | | 8,855 | | (983,162) |
| Pro Forma Consolidated EBITDAX | $76,263,898 | | $61,248,635 | | $56,314,582 | | $53,970,543 | | $247,797,658 |
| Non-cash charges acceptable to Administrative Agent: | | | | | |
| Asset retirement obligation accretion | $352,184 | | $354,195 | | $323,085 | | $326,549 | | |
| Unrealized loss (gain) on derivative assets | (765,898) | | (26,614,390) | | 6,999,552 | | 375,196 | | |
| Share-based compensation | 2,077,778 | | 32,087 | | 1,672,320 | | 1,690,958 | | |
| Total non-cash charges acceptable to Administrative Agent | $1,664,064 | | $(26,228,108) | | $8,994,957 | | $2,392,703 | | |
| As of | | | | |
| March 31, | Corresponding | | | |
| | 2025 | Leverage Ratio | | | |
| Leverage Ratio Covenant: | | | | | |
| Revolving line of credit | $460,000,000 | | 1.86 | | | | |
| Lime Rock deferred payment | 10,000,000 | | 0.04 | | | | |
| Consolidated Total Debt | $470,000,000 | | 1.90 | | | | |
| Pro Forma Consolidated EBITDAX | 247,797,658 | | | | | |
| Leverage Ratio | 1.90 | | | | | |
| Maximum Allowed | ≤ 3.00x | | | | |
All-In Cash Operating Costs
The Company defines All-In Cash Operating Costs, a non-GAAP financial measure, as “all in cash” costs which includes lease operating expenses, G&A costs excluding share-based compensation, net interest expense (including interest income and expense, excluding amortization of deferred financing costs), 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 |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| All-In Cash Operating Costs: | | | |
| Lease operating expenses (including workovers) | $18,122,344 | | $18,911,801 | | $19,677,552 | |
| G&A excluding share-based compensation | 5,913,970 | | 6,555,750 | | 6,929,018 | |
| Net interest expense (excluding amortization of deferred financing costs) | 7,834,932 | | 8,374,281 | | 8,170,235 | |
| Operating lease expense | 175,091 | | 175,090 | | 175,091 | |
| Oil and natural gas production taxes | 3,553,891 | | 3,224,183 | | 3,584,455 | |
| Ad valorem taxes | 2,202,537 | | 2,279,266 | | 1,532,108 | |
| Gathering, transportation and processing costs | 117,049 | | 121,097 | | 203,612 | |
| All-in cash operating costs | $37,919,814 | | $39,641,468 | | $40,272,071 | |
| Boe | | 1,741,581 | | 1,886,755 | | 1,655,259 |
| All-in cash operating costs per Boe | $21.77 | | $21.01 | | $24.33 | |
Cash Operating Margin
The Company defines Cash Operating Margin, a non-GAAP financial measure, as realized revenues per Boe less “all-in cash operating costs” per Boe. Management believes that this metric provides useful additional information to investors to assess the Company’s operating margins in comparison to its peers, which may vary from company to company.
| (Unaudited for All Periods) |
|---|
| Three Months Ended |
|---|
| March 31, | December 31, | March 31, |
|---|
| 2026 | 2025 | 2025 |
|---|
| Cash Operating Margin | | | |
| Realized revenues per Boe | $42.30 | | $35.45 | | $47.78 | |
| All-in cash operating costs per Boe | 21.77 | | 21.01 | | 24.33 | |
| Cash Operating Margin per Boe | $20.53 | | $14.44 | | $23.45 | |