Hedge losses drive Q1 2026 net loss at Riley Permian (NYSE: REPX)
Filing Impact
Filing Sentiment
Form Type
10-Q
Riley Exploration Permian, Inc. reported a sharp swing to a Q1 2026 net loss of $70.4M, driven mainly by a large $127.0M loss on commodity and interest rate derivatives. Core operations were stronger, with oil and natural gas sales, net rising 11% to $113.9M as production grew to 35,600 Boe/d, up from 24,433 Boe/d.
Higher volumes, including from the 2025 Silverback acquisition, lifted oil, gas and NGL output, but severe negative gas and NGL realizations after GP&T costs reduced revenue quality. Operating cash flow was $47.2M, roughly matching accrual capital expenditures of $47.1M. Total debt was $240.7M against a $400M borrowing base, and the company continued returning capital via an $8.6M quarterly dividend and share repurchases.
Positive
- None.
Negative
- Large non‑cash derivative loss and higher working capital deficit: A $126.97M loss on derivatives drove a Q1 net loss of $70.4M and raised current derivative liabilities to $77.9M, materially increasing earnings volatility and contributing to a $180.6M working capital deficit.
Insights
Strong production growth but large non‑cash hedge losses drove a Q1 net loss.
Riley Permian increased net oil and gas sales to $113.9M with production up to 35,600 Boe/d, helped by the Silverback acquisition and new wells. Operating metrics like LOE and G&A rose, but remain proportionate to the larger asset base.
The key swing factor was a $126.97M loss on derivatives, mostly non‑cash mark‑to‑market, turning solid operating income of $43.7M into a net loss of $70.4M. This also expanded current derivative liabilities and the working capital deficit.
Leverage appears manageable with total debt of $240.7M versus a $400M borrowing base and $293M availability. Investors focused on sustainability may track future derivative impacts, dividend continuity, and how incremental New Mexico midstream capacity and the RPC Power venture affect realized prices and operating costs in subsequent quarters.
Key Figures
Oil & gas sales, net: $113.9M
Net income (loss): ($70.4M)
Loss on derivatives, net: ($127.0M)
+5 more
8 metrics
Oil & gas sales, net
$113.9M
Three months ended March 31, 2026
Net income (loss)
($70.4M)
Three months ended March 31, 2026
Loss on derivatives, net
($127.0M)
Three months ended March 31, 2026
Net cash from operating activities
$47.2M
Three months ended March 31, 2026
Total debt
$240.7M
As of March 31, 2026, Credit Facility plus Senior Notes
Total assets
$1.18B
As of March 31, 2026
Average daily production
35,600 Boe/d
Three months ended March 31, 2026
Quarterly dividend declared
$0.40/share
Dividend declared April 15, 2026 for payment May 13, 2026
Key Terms
Asset Retirement Obligation, Boe/d, costless collars, Monte Carlo simulation, +2 more
6 terms
Asset Retirement Obligation financial
"Components of the changes in ARO for the three months ended March 31, 2026"
A liability recorded for the future cost to retire, dismantle or clean up a long-lived asset — for example removing an oil rig, closing a mine, or decommissioning a plant. Investors care because it reduces reported profit and ties up capital: companies must estimate and set aside money now for a known future expense, and changes to that estimate can swing earnings, debt ratios and the company’s cash needs much like setting aside savings to repair or return a rented property later.
Boe/d financial
"Daily equivalent production (Boe/d) | 35,600 | 24,433"
A measure of energy production that converts oil and gas output into a single daily figure — barrels of oil equivalent per day — so different fuels can be compared on the same scale. Think of it like converting miles and kilometers into one unit before comparing distances: investors use boe/d to judge how much total hydrocarbon output a company generates, estimate revenue potential, and compare production efficiency across firms or projects.
costless collars financial
"oil and natural gas derivative contracts consisted of fixed price swaps, costless collars and basis swaps"
A costless collar is a hedging strategy where an investor buys a protective option that limits losses and simultaneously sells an option that caps gains so the two premiums roughly cancel out. Think of it like buying insurance on a car while agreeing to share any big windfall from its sale with the insurer — it protects your downside without an upfront payment, but it also limits how much you can profit. Investors use it to reduce risk on a position while preserving capital and avoiding immediate cash outlay.
Monte Carlo simulation financial
"The earnout payments in connection with the Silverback Acquisition were valued using a Monte Carlo simulation model"
A Monte Carlo simulation is a computerized way to model many possible future outcomes by running thousands of randomized “what-if” scenarios, like rolling dice repeatedly to see the range of results. For investors it shows the probability of different returns, losses, or timing outcomes under varied assumptions, helping quantify uncertainty and compare risk — similar to using many practice runs to judge how often a plan succeeds or fails.
Credit Facility financial
"provides for a Credit Facility with a borrowing base of $400 million"
A credit facility is a flexible loan arrangement that allows a borrower to access funds up to a set limit whenever needed, similar to a company having an overdraft option on a bank account. It matters to investors because it indicates how easily a business can secure cash when required, affecting its ability to manage expenses, invest, or respond to financial challenges.
Senior Notes financial
"10.50% senior unsecured notes with final maturity in April 2028"
Senior notes are a type of loan that a company borrows from investors, promising to pay it back with interest. They are called "senior" because in case the company faces financial trouble, these lenders are paid back before others. This makes senior notes safer for investors compared to other types of loans or bonds.
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
| FORM | |||||
| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||
For the quarterly period ended March 31, 2026
OR
| TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||
Commission file number 001-15555
(Exact name of registrant as specified in its charter)
| (State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | |||||||
| (Address of Principal Executive Offices) | (Zip Code) | |||||||
Registrant's telephone number, including area code: (405 ) 415-8699
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered | ||||||
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports); and (2) has been subject to such filing requirements for the past 90 days. Yes x No o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act. (Check one):
| Large accelerated filer | o | x | |||||||||
| Non-accelerated filer | o | Smaller reporting company | |||||||||
| 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. o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes o No x
The total number of shares of common stock, par value $0.001 per share, outstanding as of May 4, 2026, was 21,695,947 .
| RILEY EXPLORATION PERMIAN, INC. | ||||||||
| FORM 10-Q | ||||||||
QUARTERLY REPORT ON FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2026 | ||||||||
| TABLE OF CONTENTS | ||||||||
| Page | ||||||||
Part I. FINANCIAL INFORMATION | ||||||||
Item 1. | Financial Statements | 6 | ||||||
Condensed Consolidated Balance Sheets | 6 | |||||||
Condensed Consolidated Statements of Operations | 7 | |||||||
Condensed Consolidated Statements of Changes in Shareholders' Equity | 8 | |||||||
Condensed Consolidated Statements of Cash Flows | 9 | |||||||
Notes to the Condensed Consolidated Financial Statements | 11 | |||||||
Item 2. | Management's Discussion and Analysis of Financial Condition and Results of Operations | 31 | ||||||
Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 39 | ||||||
Item 4. | Controls and Procedures | 40 | ||||||
Part II. OTHER INFORMATION | ||||||||
Item 1. | Legal Proceedings | 41 | ||||||
Item 1A. | Risk Factors | 41 | ||||||
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 42 | ||||||
Item 5. | Other Information | 42 | ||||||
Item 6. | Exhibits | 43 | ||||||
Signatures | 44 | |||||||
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DEFINITIONS
As used in this Quarterly Report on Form 10-Q (the "Quarterly Report"), unless otherwise noted or the context otherwise requires, we refer to Riley Exploration Permian, Inc., together with its consolidated subsidiaries, as "Riley Permian," "REPX," "the Company," "Registrant," "we," "our," or "us." In addition, this Quarterly Report includes certain terms commonly used in the oil and natural gas industry, and the following are abbreviations and definitions of certain terms used within this Quarterly Report:
| Measurements. | |||||
| Bbl | One barrel or 42 U.S. gallons liquid volume of oil or other liquid hydrocarbons | ||||
| Boe | One stock tank barrel equivalent of oil, calculated by converting gas volumes to equivalent oil barrels at a ratio of 6 thousand cubic feet of gas to 1 barrel of oil and by converting NGL volumes to equivalent oil barrels at a ratio of 1 barrel of NGL to 1 barrel of oil | ||||
| Boe/d | Stock tank barrel equivalent of oil per day | ||||
| Btu | British thermal unit. One British thermal unit is the amount of heat required to raise the temperature of one pound of water by one degree Fahrenheit | ||||
| MBbl | One thousand barrels of oil or other liquid hydrocarbons | ||||
| MBoe | One thousand Boe | ||||
| MBoe/d | One thousand Boe per day | ||||
| Mcf | One thousand cubic feet of gas | ||||
| MMBtu | One million British thermal units | ||||
| MMcf | One million cubic feet of gas | ||||
| Abbreviations. | |||||
| ARO | Asset Retirement Obligation | ||||
| ATM | At-the-market equity sales program | ||||
CODM | Chief Operating Decision Maker as defined by the FASB under the Accounting Standards Codification 280. Together, the Chief Executive Officer, Chief Financial Officer, Chief Operating Officer, and Chief Accounting Officer form a collaborative team that functions as the CODM. | ||||
Credit Facility | A credit agreement among Riley Exploration - Permian, LLC, as borrower, and Riley Exploration Permian, Inc, as parent guarantor, with Truist Bank and certain lenders party thereto, as amended | ||||
ERCOT | Electric Reliability Council of Texas | ||||
| FASB | Financial Accounting Standards Board | ||||
| GP&T costs | Gathering, processing and transportation costs | ||||
| NGL | Natural gas liquids | ||||
| NYMEX | New York Mercantile Exchange | ||||
| NYSE | New York Stock Exchange | ||||
| Oil | Crude oil and condensate | ||||
OPEC+ | Organization of the Petroleum Exporting Countries ("OPEC") members and non-OPEC allies | ||||
| RRC | Railroad Commission of Texas | ||||
| SEC | Securities and Exchange Commission | ||||
Senior Notes | The Company's unsecured 10.5% senior notes due April 2028 | ||||
| U.S. GAAP | Accounting principles generally accepted in the United States of America | ||||
| WTI | West Texas Intermediate | ||||
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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS
This Quarterly Report 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. All statements, other than statements of historical fact, contained in this Quarterly Report that include information concerning our possible or assumed future results of operations, business strategies, need for financing, competitive position and potential growth opportunities represent management's beliefs and assumptions based on currently available information and they do not consider the effects of future legislation or regulations. Forward-looking statements include all statements that are not historical facts and can be identified by the use of forward-looking terminology such as the words "believes," "intends," "may," "should," "anticipates," "expects," "could," "plans," "estimates," "projects," "targets" or comparable terminology or by discussions of strategy or trends. Such statements by their nature involve risks and uncertainties that could significantly affect expected results, and actual future results could differ materially from those described in such forward-looking statements.
Among the factors that could cause actual future results to differ materially are the risks and uncertainties discussed under "Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Part II, Item 1A. Risk Factors" in this Quarterly Report and "Part I, Item 1A. Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2025 (the "2025 Annual Report"). We continue to face many risks and uncertainties including, but not limited to:
•the volatility of oil, natural gas and NGL prices, including basis differentials between published indices and the prices we actually receive for our production;
•regional supply and demand factors, any delays, curtailment delays or interruptions of production, and any governmental order, rule or regulation that may impose production limits;
•cost and availability of gathering, pipeline, refining, transportation, power and other midstream and downstream activities, which could result in a prolonged shut-in of our wells that may adversely affect our reserves, financial condition and results of operations;
•severe weather and other risks that lead to a lack of any available markets;
•our ability to successfully complete mergers, acquisitions or divestitures;
•the inability or failure of the Company to successfully integrate the acquired assets into our operations and development activities;
•the potential delays in the development, construction or start-up of planned projects;
•failure to realize any of the anticipated benefits of our joint ventures or other equity investments;
•risks relating to our operations, including development drilling and testing results and performance of acquired properties and newly drilled wells;
•inability to prove up undeveloped acreage and maintain production on leases;
•any reduction in our borrowing base on our Credit Facility from time to time and our ability to repay any excess borrowings as a result of such reduction;
•the impact of our derivative strategy and the results of future settlement;
•our ability to comply with the financial covenants contained in our Credit Facility and in our Senior Notes;
•changes in general economic, business or industry conditions, including changes in inflation rates, interest rates and foreign currency exchange rates;
•conditions in the capital, financial and credit markets and our ability to obtain capital needed to fund our exploration and development on favorable terms or at all;
•the loss of certain tax deductions;
•risks associated with executing our business strategy, including any changes in our strategy;
•risks associated with concentration of operations in one major geographic area;
•legislative or regulatory changes, including initiatives related to hydraulic fracturing, regulation of greenhouse gases, water conservation, seismic activity, weatherization, or protection of certain species of wildlife, or of sensitive environmental areas;
•the ability to receive drilling and other permits or approvals and rights-of-way in a timely manner (or at all), which may be restricted by governmental regulation and legislation;
•restrictions on the use of water, including limits on the use of produced water and a moratorium on new produced water well permits recently imposed by the RRC in an effort to control induced seismicity in the Permian Basin;
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•changes in government environmental policies and other environmental risks;
•the availability of drilling equipment and the timing of production;
•tax consequences of business transactions;
•public health crises, such as pandemics and epidemics, and any related government policies and actions and the effects of such public health crises on the oil and natural gas industry, pricing and demand for oil and natural gas and supply chain logistics;
•general domestic and international economic, market and political conditions, including military conflicts, global economic growth, unpredictability of new tariffs, actions of OPEC+ countries and changes to the current political environment under the current administration;
•risks related to litigation; and
•cybersecurity threats, technology system failures and data security issues.
In light of such risks and uncertainties, we caution you not to place undue reliance on these forward-looking statements. These forward-looking statements speak only as of the date of this Quarterly Report, or if earlier, as of the date they were made. We do not intend to, and disclaim any obligation to, update or revise any forward-looking statements unless required by securities law.
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Part I. FINANCIAL INFORMATION
Item 1. Financial Statements
| RILEY EXPLORATION PERMIAN, INC. | ||||||||||||||||||||
| CONDENSED CONSOLIDATED BALANCE SHEETS | ||||||||||||||||||||
| (Unaudited) | ||||||||||||||||||||
| March 31, 2026 | December 31, 2025 | |||||||||||||||||||
| (In thousands, except share amounts) | ||||||||||||||||||||
| Assets | ||||||||||||||||||||
| Current Assets: | ||||||||||||||||||||
| Cash | $ | $ | ||||||||||||||||||
| Accounts receivable, net | ||||||||||||||||||||
| Prepaid expenses | ||||||||||||||||||||
| Inventory | ||||||||||||||||||||
| Current derivative assets | ||||||||||||||||||||
| Total Current Assets | ||||||||||||||||||||
| Oil and natural gas properties, net (successful efforts) | ||||||||||||||||||||
| Other property and equipment, net | ||||||||||||||||||||
| Non-current derivative assets | ||||||||||||||||||||
| Equity method investment | ||||||||||||||||||||
| Funds held in escrow | ||||||||||||||||||||
| Other non-current assets, net | ||||||||||||||||||||
| Total Assets | $ | $ | ||||||||||||||||||
| Liabilities and Shareholders' Equity | ||||||||||||||||||||
| Current Liabilities: | ||||||||||||||||||||
| Accounts payable | $ | $ | ||||||||||||||||||
| Accrued liabilities | ||||||||||||||||||||
| Revenue payable | ||||||||||||||||||||
| Current derivative liabilities | ||||||||||||||||||||
| Current portion of long-term debt | ||||||||||||||||||||
| Other current liabilities | ||||||||||||||||||||
| Total Current Liabilities | ||||||||||||||||||||
| Non-current derivative liabilities | ||||||||||||||||||||
| Asset retirement obligations | ||||||||||||||||||||
| Long-term debt | ||||||||||||||||||||
| Deferred tax liabilities | ||||||||||||||||||||
| Other non-current liabilities | ||||||||||||||||||||
| Total Liabilities | ||||||||||||||||||||
| Commitments and Contingencies (Note 15) | ||||||||||||||||||||
| Shareholders' Equity: | ||||||||||||||||||||
Preferred stock, $ | ||||||||||||||||||||
Common stock, $ | ||||||||||||||||||||
| Additional paid-in capital | ||||||||||||||||||||
| Retained earnings | ||||||||||||||||||||
| Total Shareholders' Equity | ||||||||||||||||||||
| Total Liabilities and Shareholders' Equity | $ | $ | ||||||||||||||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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| RILEY EXPLORATION PERMIAN, INC. | ||||||||||||||||||||||||||||||||||||||
| CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS | ||||||||||||||||||||||||||||||||||||||
| (Unaudited) | ||||||||||||||||||||||||||||||||||||||
| Three Months Ended March 31, | ||||||||||||||||||||||||||||||||||||||
| 2026 | 2025 | |||||||||||||||||||||||||||||||||||||
| (In thousands, except per share amounts) | ||||||||||||||||||||||||||||||||||||||
| Revenues: | ||||||||||||||||||||||||||||||||||||||
| Oil and natural gas sales, net | $ | $ | ||||||||||||||||||||||||||||||||||||
| Total Revenues | ||||||||||||||||||||||||||||||||||||||
| Costs and Expenses: | ||||||||||||||||||||||||||||||||||||||
| Lease operating expenses | ||||||||||||||||||||||||||||||||||||||
| Production and ad valorem taxes | ||||||||||||||||||||||||||||||||||||||
| Exploration costs | ||||||||||||||||||||||||||||||||||||||
| Depletion, depreciation, amortization and accretion | ||||||||||||||||||||||||||||||||||||||
| General and administrative: | ||||||||||||||||||||||||||||||||||||||
| Administrative costs | ||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense | ||||||||||||||||||||||||||||||||||||||
| Total Costs and Expenses | ||||||||||||||||||||||||||||||||||||||
| Income from Operations | ||||||||||||||||||||||||||||||||||||||
| Other Expense: | ||||||||||||||||||||||||||||||||||||||
| Interest expense, net | ( | ( | ||||||||||||||||||||||||||||||||||||
| Loss on derivatives, net | ( | ( | ||||||||||||||||||||||||||||||||||||
| Loss from equity method investment | ( | ( | ||||||||||||||||||||||||||||||||||||
Loss on acquisitions and divestitures, net | ( | |||||||||||||||||||||||||||||||||||||
| Total Other Expense | ( | ( | ||||||||||||||||||||||||||||||||||||
| Net Income (Loss) from Operations before Income Taxes | ( | |||||||||||||||||||||||||||||||||||||
| Income tax benefit (expense) | ( | |||||||||||||||||||||||||||||||||||||
| Net Income (Loss) | $ | ( | $ | |||||||||||||||||||||||||||||||||||
| Net Income (Loss) per Share: | ||||||||||||||||||||||||||||||||||||||
| Basic | $ | ( | $ | |||||||||||||||||||||||||||||||||||
| Diluted | $ | ( | $ | |||||||||||||||||||||||||||||||||||
| Weighted Average Common Shares Outstanding: | ||||||||||||||||||||||||||||||||||||||
| Basic | ||||||||||||||||||||||||||||||||||||||
| Diluted | ||||||||||||||||||||||||||||||||||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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| RILEY EXPLORATION PERMIAN, INC. | ||||||||||||||||||||||||||||||||||||||||||||
| CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY | ||||||||||||||||||||||||||||||||||||||||||||
| (Unaudited) | ||||||||||||||||||||||||||||||||||||||||||||
(In thousands) | ||||||||||||||||||||||||||||||||||||||||||||
| Shareholders' Equity | ||||||||||||||||||||||||||||||||||||||||||||
| Common Stock | ||||||||||||||||||||||||||||||||||||||||||||
| Shares | Amount | Additional Paid-in Capital | Retained Earnings | Total Shareholders' Equity | ||||||||||||||||||||||||||||||||||||||||
| Balance, December 31, 2025 | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense | — | — | — | |||||||||||||||||||||||||||||||||||||||||
| Repurchased shares for tax withholding | — | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Dividends declared | — | — | — | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Repurchase and retirement of shares | ( | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Net loss | — | — | — | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Balance, March 31, 2026 | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||
| Balance, December 31, 2024 | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense | — | — | ||||||||||||||||||||||||||||||||||||||||||
| Repurchased shares for tax withholding | ( | — | ( | — | ( | |||||||||||||||||||||||||||||||||||||||
| Dividends declared | — | — | — | ( | ( | |||||||||||||||||||||||||||||||||||||||
| Net income | — | — | — | |||||||||||||||||||||||||||||||||||||||||
| Balance, March 31, 2025 | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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| RILEY EXPLORATION PERMIAN, INC. | ||||||||||||||||||||
| CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS | ||||||||||||||||||||
| (Unaudited) | ||||||||||||||||||||
| Three Months Ended March 31, | ||||||||||||||||||||
| 2026 | 2025 | |||||||||||||||||||
| (In thousands) | ||||||||||||||||||||
| Cash Flows from Operating Activities: | ||||||||||||||||||||
| Net income (loss) | $ | ( | $ | |||||||||||||||||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | ||||||||||||||||||||
| Exploratory well costs and lease expirations | ||||||||||||||||||||
| Depletion, depreciation, amortization and accretion | ||||||||||||||||||||
| Loss on derivatives, net | ||||||||||||||||||||
| Settlements on derivative contracts | ( | |||||||||||||||||||
| Amortization of deferred financing costs and discount | ||||||||||||||||||||
| Stock-based compensation expense | ||||||||||||||||||||
Deferred income tax benefit | ( | ( | ||||||||||||||||||
| Loss from equity method investment | ||||||||||||||||||||
Loss on acquisitions and divestitures, net | ||||||||||||||||||||
| Other | ( | |||||||||||||||||||
| Changes in operating assets and liabilities | ||||||||||||||||||||
| Accounts receivable, net | ( | |||||||||||||||||||
| Prepaid expenses | ( | ( | ||||||||||||||||||
Inventory | ( | ( | ||||||||||||||||||
| Other non-current assets, net | ( | |||||||||||||||||||
| Accounts payable and accrued liabilities | ( | |||||||||||||||||||
| Revenue payable | ( | ( | ||||||||||||||||||
| Other current liabilities | ( | |||||||||||||||||||
| Net Cash Provided by Operating Activities | ||||||||||||||||||||
| Cash Flows from Investing Activities: | ||||||||||||||||||||
| Additions to oil and natural gas properties | ( | ( | ||||||||||||||||||
| Additions to midstream property and equipment | ( | ( | ||||||||||||||||||
| Additions to other property and equipment | ( | ( | ||||||||||||||||||
| Acquisitions of oil and natural gas properties | ( | |||||||||||||||||||
| Acquisitions of land | ( | |||||||||||||||||||
| Proceeds from divestitures | ||||||||||||||||||||
| Contributions to equity method investment | ( | ( | ||||||||||||||||||
| Distributions from equity method investment | ||||||||||||||||||||
| Net Cash Used in Investing Activities | ( | ( | ||||||||||||||||||
| Cash Flows from Financing Activities: | ||||||||||||||||||||
| Deferred financing costs | ( | ( | ||||||||||||||||||
| Proceeds from Credit Facility | ||||||||||||||||||||
| Repayments under Credit Facility | ( | ( | ||||||||||||||||||
| Repayments of Senior Notes | ( | ( | ||||||||||||||||||
| Payment of cash dividends | ( | ( | ||||||||||||||||||
| Repurchase of common shares | ( | |||||||||||||||||||
| Repurchase of common shares for tax withholding and other | ( | ( | ||||||||||||||||||
| Net Cash Used in Financing Activities | ( | ( | ||||||||||||||||||
| Net Decrease in Cash | ( | ( | ||||||||||||||||||
Cash, Beginning of Period | ||||||||||||||||||||
Cash, End of Period | $ | $ | ||||||||||||||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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| RILEY EXPLORATION PERMIAN, INC. | ||||||||||||||||||||
| CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - (Continued) | ||||||||||||||||||||
| (Unaudited) | ||||||||||||||||||||
| Three Months Ended March 31, | ||||||||||||||||||||
| 2026 | 2025 | |||||||||||||||||||
| (In thousands) | ||||||||||||||||||||
| Supplemental Disclosure of Cash Flow Information | ||||||||||||||||||||
| Cash Paid For: | ||||||||||||||||||||
| Interest, net of capitalized interest | $ | $ | ||||||||||||||||||
| Income taxes | $ | $ | ||||||||||||||||||
| Non-cash Investing and Financing Activities: | ||||||||||||||||||||
| Changes in capital expenditures in accounts payable and accrued liabilities | $ | $ | ||||||||||||||||||
| Transfer of inventory to oil and natural gas properties | $ | ( | $ | |||||||||||||||||
| Right-of-use assets obtained in exchange for operating lease liability | $ | $ | ||||||||||||||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
(1) Nature of Business
Riley Permian is a growth-oriented, independent oil and natural gas company focused on horizontal drilling of conventional oil-saturated and liquids-rich formations in the Permian Basin that produce long-term cash flows. The majority of our acreage is located in Yoakum County, Texas, which represents our Champions field and Eddy County, New Mexico, which represents our Red Lake field.
(2) Basis of Presentation
These unaudited condensed consolidated financial statements as of March 31, 2026, and for the three months ended March 31, 2026, and 2025, include the accounts of Riley Permian and our consolidated subsidiaries and have been prepared in accordance with U.S. GAAP. All intercompany balances and transactions have been eliminated upon consolidation.
Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the rules and regulations of the SEC. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements included in the Company's 2025 Annual Report.
These condensed consolidated financial statements have not been audited by an independent registered public accounting firm. In the opinion of the Company’s management, the accompanying unaudited condensed consolidated financial statements contain all adjustments necessary for fair presentation of the results of operations for the periods presented, which adjustments were of a normal recurring nature, except as disclosed herein. The results of operations for the three months ended March 31, 2026, are not necessarily indicative of the results to be expected for the full-year ending December 31, 2026, for various reasons, including fluctuations in prices received for oil and natural gas, natural production declines, the uncertainty of exploration and development drilling results, fluctuations in the fair value of derivative instruments, unpredictability of new tariffs, the current and future impacts of military conflicts, changes to the political environment under the current administration and other factors.
(3) Summary of Significant Accounting Policies
Significant Estimates
The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in our condensed consolidated financial statements and accompanying notes. These estimates and assumptions may also affect disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.
The Company evaluates these estimates on an ongoing basis, using historical experience, consultation with experts and other methods the Company considers reasonable in the particular circumstances. Actual results may differ significantly from the Company’s estimates. Any effects on the Company’s business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Significant items subject to such estimates and assumptions include, but are not limited to, estimates of proved oil and natural gas reserves and related present value estimates of future net cash flows therefrom, the carrying value of oil and natural gas properties, accounts receivable, accrued capital expenditures and operating expenses, ARO, the fair value determination of acquired assets and assumed liabilities, certain tax accruals and the fair value of derivatives.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Accounts Receivable, net
Accounts receivable, net is summarized below:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
| Oil, natural gas and NGL sales | $ | $ | |||||||||
| Joint interest accounts receivable | |||||||||||
| Allowance for credit losses | ( | ( | |||||||||
| Other accounts receivable | |||||||||||
Total accounts receivable, net | $ | $ | |||||||||
As of December 31, 2024, the Company had accounts receivables, net from oil, natural gas and NGL sales of $33.6 million.
The Company estimates uncollectible amounts based on the length of time that the accounts receivable has been outstanding, historical collection experience and current and future economic and market conditions. Allowances for credit losses are recorded as reductions to the carrying values of the accounts receivable included in the Company’s condensed consolidated balance sheets and are recorded in administrative costs in our condensed consolidated statements of operations if failure to collect an estimable portion is determined to be probable.
Other Property and Equipment, net
Other property and equipment, net is summarized below:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
Furniture, fixtures and other | |||||||||||
Land | |||||||||||
Other property and equipment | $ | $ | |||||||||
Accumulated depreciation and amortization | ( | ( | |||||||||
Total other property and equipment, net | $ | $ | |||||||||
Other Non-Current Assets, net
Other non-current assets, net consisted of the following:
_____________________
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
Deferred financing costs, net (1) | $ | $ | |||||||||
| Right of use assets | |||||||||||
| Prepaid capital expenditures | |||||||||||
Deposits | |||||||||||
| Other | |||||||||||
| Total other non-current assets, net | $ | $ | |||||||||
(1)Deferred financing costs, net reflects costs associated with the Company's Credit Facility which are amortized over the term of the Credit Facility.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Accrued Liabilities
Accrued liabilities consisted of the following:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
| Accrued capital expenditures | $ | $ | |||||||||
| Accrued lease operating expenses | |||||||||||
| Accrued general and administrative costs | |||||||||||
Accrued inventory | |||||||||||
| Accrued ad valorem tax | |||||||||||
| Other accrued expenditures | |||||||||||
| Total accrued liabilities | $ | $ | |||||||||
Other Current Liabilities
Other current liabilities consisted of the following:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
| Advances from joint interest owners | $ | $ | |||||||||
| Income taxes payable | |||||||||||
| Current ARO liabilities | |||||||||||
| Current portion of earnout payments | |||||||||||
| Other | |||||||||||
Total other current liabilities | $ | $ | |||||||||
Asset Retirement Obligations
Components of the changes in ARO for the three months ended March 31, 2026, and the year ended December 31, 2025, are shown below:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
| ARO, beginning balance | $ | $ | |||||||||
| Liabilities incurred | |||||||||||
| Liabilities assumed in acquisitions | |||||||||||
Liabilities removed upon sale | ( | ( | |||||||||
| Revision of estimated obligations | |||||||||||
Liability settlements | ( | ( | |||||||||
| Accretion | |||||||||||
| ARO, ending balance | $ | $ | |||||||||
Less: current ARO (1) | ( | ( | |||||||||
| ARO, long-term | $ | $ | |||||||||
(1)Current ARO is included within other current liabilities in our accompanying condensed consolidated balance sheets.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Revenue Recognition
The following table presents oil and natural gas sales, net disaggregated by product:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Oil and natural gas sales: | |||||||||||||||||||||||
Oil sales, net | $ | $ | |||||||||||||||||||||
Natural gas sales, net | ( | ||||||||||||||||||||||
NGL sales, net | ( | ||||||||||||||||||||||
Total oil and natural gas sales, net (1) | $ | $ | |||||||||||||||||||||
(1) The Company's oil, natural gas and NGL sales are presented net of GP&T costs. These costs, related to natural gas and NGLs, at times exceeded the price received and resulted in negative average realized prices.
Recent Accounting Pronouncements
In November 2024, the FASB issued ASU 2024-03, Income Statement (Subtopic 220-40) Reporting Comprehensive Income-Expense Disaggregation Disclosures, which broadens the disclosures required for certain costs and expenses in the Company’s annual and interim consolidated financial statements. This ASU is effective prospectively for fiscal years beginning after December 15, 2026, and interim reporting periods within fiscal years beginning after December 15, 2027. The Company is currently evaluating the impact to disclosures related to our annual report for fiscal year 2027.
(4) Acquisitions and Divestitures
Silverback Acquisition
On July 1, 2025, the Company completed the acquisition of 100 % of the ownership interests of Silverback Exploration II, LLC and its subsidiaries ("Silverback") which owns oil and natural gas assets and operations located primarily in the Yeso trend of the Permian Basin in Eddy County, New Mexico for approximately $123 million, which included approximately $120 million paid in cash and approximately $3 million of estimated fair value related to potential earnout payments ("Silverback Acquisition"). The purchase price is subject to change pending final purchase price adjustments including the release of $1.2 million remaining in escrow, until one year from the closing date.
The Silverback Acquisition qualified as a business combination using the acquisition method of accounting. The assets acquired and liabilities assumed were recognized at fair value as of the acquisition date. The preliminary purchase price allocation is subject to change for up to one year subsequent to the closing date of the acquisition due to final customary purchase price adjustments. The assets acquired and liabilities assumed were recognized on the consolidated balance sheet at fair value as of the acquisition date. The fair value measurements of the oil and natural gas properties acquired and ARO assumed were derived utilizing an income approach and based, in part, on significant inputs not observable in the market. These inputs represent Level 3 measurements in the fair value hierarchy and include, but are not limited to, estimates of reserves, future development, future operating costs, future cash flows and the use of weighted average cost of capital. These inputs required the use of significant judgments and estimates at the date of valuation, and use of different estimates and judgments could yield different results.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
The following presents the allocation of the total purchase price of the Silverback Acquisition to the identified assets acquired and liabilities assumed based on estimated fair value as of the closing date of the acquisition:
Preliminary purchase price allocation as of March 31, 2026 (in thousands): | ||||||||
| Consideration: | ||||||||
| Cash consideration paid to sellers upon closing | $ | |||||||
| Preliminary estimated fair value of earnout payments | ||||||||
| Total consideration transferred | $ | |||||||
Fair value of assets acquired: | ||||||||
Cash | $ | |||||||
| Accounts receivable | ||||||||
Prepaid expenses | ||||||||
| Inventory | ||||||||
Current derivative assets | ||||||||
Oil and gas properties | ||||||||
Other property and equipment | ||||||||
Other non-current assets | ||||||||
Amount attributable to assets acquired | $ | |||||||
Fair value of liabilities assumed: | ||||||||
| Accounts payable | $ | |||||||
Accrued liabilities | ||||||||
| Revenue payable | ||||||||
| Asset retirement obligations | ||||||||
| Amount attributable to liabilities assumed | $ | |||||||
| Net assets acquired | $ | |||||||
Cash consideration included deposits into escrow of $14.2 million at signing and $6.9 million at closing for title defects. As of March 31, 2026, $4.6 million of the closing escrow was returned to the Company, $1.1 million was paid to the sellers and $1.2 million remains in escrow and is reflected as funds held in escrow in our condensed consolidated balance sheets.
The Company funded the acquisition with cash on hand and borrowings under our Credit Facility.
The Company may potentially pay the sellers quarterly earnout payments of up to $1.9 million per fiscal quarter during calendar years 2026 and 2027 if the NYMEX WTI quarterly average exceeds certain stated amounts set forth in the Purchase Agreement, ranging from $70 to $75 per barrel or higher. For the three months ended March 31, 2026, the average WTI was $72.67 . The Company remeasured the fair value of its earnout payment liability at March 31, 2026, for the remaining 7 quarters and, as a result of the increase in the WTI forward strip pricing, a $4.1 million unrealized loss was reflected in loss on acquisitions and divestitures, net in our condensed consolidated statements of operations, inclusive of the payout of $937,500 , which was realized and paid in April 2026. See additional information on the fair value measurement of the earnout payments in Note 7 - Fair Value Measurements.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Loss on acquisitions and divestitures, net consisted of the following:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
Gain on sale of oil and natural gas properties (1) | $ | $ | |||||||||||||||||||||
Loss on earnout liabilities - Silverback Acquisition | ( | ||||||||||||||||||||||
| Loss on sale of other property and equipment | ( | ||||||||||||||||||||||
Total loss on acquisitions and divestitures, net | $ | ( | $ | ||||||||||||||||||||
_____________________
Post-Acquisition Operating Results
The results of operations attributable to the Silverback Acquisition since the closing date of the acquisition have been included in the condensed consolidated statements of operations and include $14.2 million of total revenues and $8.4 million of earnings, which represents total revenues less production taxes and lease operating expenses ("LOE"), for the three months ended March 31, 2026.
Pro Forma Operating Results (Unaudited)
The results of operations of the Silverback Acquisition have been included in the Company's condensed consolidated financial statements since the closing date of the acquisition. The following supplemental, unaudited pro forma combined financial information for the three months ended March 31, 2025, reflect the consolidated results of operations of the Company as if the Silverback Acquisition had occurred on January 1, 2024. The information below reflects pro forma adjustments based on available information and certain assumptions that the Company believes are factual and supportable. The unaudited pro forma information includes adjustments for (i) transaction costs being reclassified to the first quarter of 2024 instead of being recorded in the year ended December 31, 2025, (ii) depletion, depreciation and amortization expense and (iii) interest expense related to the financing for the Silverback Acquisition. In addition, the pro forma information has been effected for income taxes with a blended statutory rate of 25.7 % for the three months ended March 31, 2025.
Three Months Ended | ||||||||||||||||||||||||||||||||
| March 31, 2025 | ||||||||||||||||||||||||||||||||
| (In thousands, except per share amounts) | ||||||||||||||||||||||||||||||||
Total revenues | $ | |||||||||||||||||||||||||||||||
| Net income | $ | |||||||||||||||||||||||||||||||
| Basic net income per common share | $ | |||||||||||||||||||||||||||||||
| Diluted net income per common share | $ | |||||||||||||||||||||||||||||||
The unaudited pro forma combined financial information is for informational purposes only and is not intended to represent or to be indicative of the combined results of operations that the Company would have reported had the Silverback Acquisition been completed as of January 1, 2024, and should not be taken as indicative of the Company's future combined results of operations. The actual results may differ significantly from that reflected in the unaudited pro forma combined financial information for a number of reasons, including, but not limited to, differences in assumptions used to prepare the unaudited pro forma combined financial information and actual results.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
(5) Oil and Natural Gas Properties
Oil and natural gas properties, net are summarized below:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
| Proved | $ | $ | |||||||||
| Unproved | |||||||||||
| Work-in-progress | |||||||||||
Oil and natural gas properties | $ | $ | |||||||||
| Accumulated depletion, amortization and impairment | ( | ( | |||||||||
| Total oil and natural gas properties, net | $ | $ | |||||||||
Depletion expense for proved oil and natural gas properties was $24.8 million and $17.5 million, respectively, for the three months ended March 31, 2026, and 2025.
(6) Derivative Instruments
Oil and Natural Gas Contracts
The Company uses commodity based derivative contracts to reduce exposure to fluctuations in oil and natural gas prices. While the use of these contracts partially limits the downside risk for adverse price changes, their use also partially limits future revenues from favorable price changes. We have not designated our derivative contracts as hedges for accounting purposes, and therefore changes in the fair value of derivatives are included and recognized in other expense in our accompanying condensed consolidated statements of operations.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
As of March 31, 2026, the Company’s oil and natural gas derivative contracts consisted of fixed price swaps, costless collars and basis swaps. The following table summarizes the open financial derivative positions as of March 31, 2026, related to our future oil and natural gas production:
| 2026 | 2027 | 2028 | ||||||||||||||||||||||||||||||||||||||||||||||||
| Second Quarter | Third Quarter | Fourth Quarter | First Quarter | Second Quarter | Third Quarter | Fourth Quarter | First Quarter | |||||||||||||||||||||||||||||||||||||||||||
| Oil | ||||||||||||||||||||||||||||||||||||||||||||||||||
WTI Oil Swaps | ||||||||||||||||||||||||||||||||||||||||||||||||||
Volume (Bbl) | ||||||||||||||||||||||||||||||||||||||||||||||||||
Weighted average price ($/Bbl) | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||
WTI Oil Collars | ||||||||||||||||||||||||||||||||||||||||||||||||||
Volume (Bbl) | ||||||||||||||||||||||||||||||||||||||||||||||||||
Weighted average floor price ($/Bbl) | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||
Weighted average ceiling price ($/Bbl) | $ | $ | $ | $ | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||
| Natural Gas | ||||||||||||||||||||||||||||||||||||||||||||||||||
Henry Hub Natural Gas Swaps | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Volume (MMBtu) | ||||||||||||||||||||||||||||||||||||||||||||||||||
Weighted average price ($/MMBtu) | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||
Henry Hub Natural Gas Collars | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Volume (MMBtu) | ||||||||||||||||||||||||||||||||||||||||||||||||||
Weighted average floor price ($/MMBtu) | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||
Weighted average ceiling price ($/MMBtu) | $ | $ | $ | $ | ||||||||||||||||||||||||||||||||||||||||||||||
Waha Basis Swaps | ||||||||||||||||||||||||||||||||||||||||||||||||||
| Volume (MMBtu) | ||||||||||||||||||||||||||||||||||||||||||||||||||
Weighted average price ($/MMBtu) | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | $ | ( | ||||||||||||||||||||||||||||||||||
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Interest Rate Contracts
The Company entered into floating-to-fixed interest rate swaps, in which it will receive a floating market rate equal to one-month Chicago Mercantile Exchange Term Secured Overnight Financing Rate ("SOFR") Rate and will pay a fixed interest rate to manage future interest rate exposure related to the Company’s Credit Facility.
The following table summarizes the open interest rate derivative positions as of March 31, 2026:
| Open Coverage Period | Position | Notional Amount | Fixed Rate | |||||||||||||||||
| (In thousands) | ||||||||||||||||||||
| April 2026 - April 2026 | Long | $ | % | |||||||||||||||||
| April 2026 - April 2026 | Long | $ | % | |||||||||||||||||
| April 2026 - April 2027 | Long | $ | % | |||||||||||||||||
Balance Sheet Presentation of Derivatives
The following tables present the location and fair value of the Company’s derivative contracts included in our accompanying condensed consolidated balance sheets:
| March 31, 2026 | ||||||||||||||||||||
| Balance Sheet Classification | Gross Fair Value | Amounts Netted | Net Fair Value | |||||||||||||||||
| (In thousands) | ||||||||||||||||||||
| Current derivative assets | $ | $ | ( | $ | ||||||||||||||||
| Non-current derivative assets | ( | |||||||||||||||||||
| Current derivative liabilities | ( | ( | ||||||||||||||||||
| Non-current derivative liabilities | ( | ( | ||||||||||||||||||
| Total | $ | ( | $ | — | $ | ( | ||||||||||||||
| December 31, 2025 | ||||||||||||||||||||
| Balance Sheet Classification | Gross Fair Value | Amounts Netted | Net Fair Value | |||||||||||||||||
| (In thousands) | ||||||||||||||||||||
| Current derivative assets | $ | $ | ( | $ | ||||||||||||||||
| Non-current derivative assets | ( | |||||||||||||||||||
| Current derivative liabilities | ( | ( | ||||||||||||||||||
| Non-current derivative liabilities | ( | ( | ||||||||||||||||||
| Total | $ | $ | — | $ | ||||||||||||||||
The following table presents the components of the Company's loss on derivatives, net for the periods presented below:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Settlements on derivative contracts | $ | ( | $ | ||||||||||||||||||||
| Non-cash loss on derivatives | ( | ( | |||||||||||||||||||||
| Loss on derivatives, net | $ | ( | $ | ( | |||||||||||||||||||
(7) Fair Value Measurements
The FASB has established a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy consists of three broad levels. Level 1 inputs are the highest priority and consist of unadjusted quoted prices in active markets for identical assets and liabilities. Level 2 are inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly. Level 3 are unobservable inputs for an asset or liability.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
The carrying values of financial instruments comprising cash, payables, receivables and advances from joint interest owners approximate fair values due to the short-term maturities of these instruments and are classified as Level 1 in the fair value hierarchy. The carrying value reported for the Credit Facility approximates fair value because the underlying instruments are at interest rates which approximate current market rates. The fair value of the Senior Notes is based on estimates of current rates available for similar issuances with similar maturities and is classified as Level 2 in the fair value hierarchy. The oil and natural gas properties acquired and ARO assumed in the Silverback Acquisition in addition to the fair value of assets and liabilities when considered for impairment are considered Level 3 measurements.
Assets and Liabilities Measured on a Recurring Basis
The fair values of commodity derivatives and interest rate swaps are estimated using discounted cash flow calculations based on forward curves and are classified as Level 2 within the fair value hierarchy. The following table summarizes the Company's financial assets and liabilities that were accounted for at fair value on a recurring basis by level within the fair value hierarchy:
| March 31, 2026 | |||||||||||||||||||||||
| Level 1 | Level 2 | Level 3 | Total | ||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Financial assets: | |||||||||||||||||||||||
| Commodity derivative assets | $ | $ | $ | $ | |||||||||||||||||||
| Financial liabilities: | |||||||||||||||||||||||
| Commodity derivative liabilities | $ | $ | ( | $ | $ | ( | |||||||||||||||||
| Interest rate liabilities | $ | $ | ( | $ | $ | ( | |||||||||||||||||
Silverback earnout payment liabilities | $ | $ | $ | ( | $ | ( | |||||||||||||||||
| December 31, 2025 | |||||||||||||||||||||||
| Level 1 | Level 2 | Level 3 | Total | ||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Financial assets: | |||||||||||||||||||||||
| Commodity derivative assets | $ | $ | $ | $ | |||||||||||||||||||
| Financial liabilities: | |||||||||||||||||||||||
| Commodity derivative liabilities | $ | $ | ( | $ | $ | ( | |||||||||||||||||
| Interest rate liabilities | $ | $ | ( | $ | $ | ( | |||||||||||||||||
| Silverback earnout payment liabilities | $ | $ | $ | ( | $ | ( | |||||||||||||||||
Silverback Earnout Payments
The earnout payments in connection with the Silverback Acquisition were valued using a Monte Carlo simulation model that incorporated forward strip pricing as of March 31, 2026. The valuation process involved modeling the potential earnout payments over numerous scenarios based on WTI futures prices. The average expected value from the simulations was then discounted using the Company's weighted average cost of debt. Based on the forward strip pricing as of March 31, 2026, the earnout payment liability was increased from $3.1 million to $7.2 million, which includes $937,500 realized and paid in April 2026 and $6.3 million unrealized. The fair value of the unrealized earnout payments is considered a Level 3 measurement due to the unobservable inputs including volatility and the discount rate, as well as the detailed modeling required to estimate fair value. See Note 4 - Acquisitions and Divestitures for additional information on the earnout payments. The following table summarizes the changes in the fair value of our Silverback earnout payments, in addition to the range and arithmetic mean of the significant unobservable inputs used in the Level 3 fair value measurement:
Unobservable Inputs | |||||||||||||||||||||||
| Fair Value (In thousands) | Valuation Technique | WTI Futures (Arithmetic Average) | |||||||||||||||||||||
| December 31, 2025 | $ | Monte Carlo | $ | ||||||||||||||||||||
Loss on earnout liabilities | |||||||||||||||||||||||
| March 31, 2026 | $ | Monte Carlo | $ | ||||||||||||||||||||
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
As of March 31, 2026, $4.5 million, which includes the earned payout of $937,500 for the first quarter of 2026, is accrued in other current liabilities and $2.7 million is accrued in other long-term liabilities in our accompanying condensed consolidated balance sheets.
Liabilities Not Measured on a Recurring Basis
The following table summarizes the fair value and carrying amount of the Company's financial instruments:
| March 31, 2026 | December 31, 2025 | ||||||||||||||||||||||
| Carrying Amount | Fair Value | Carrying Amount | Fair Value | ||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
Credit Facility (Level 2) | $ | $ | $ | $ | |||||||||||||||||||
Senior Notes (Level 2)(1) | $ | $ | $ | $ | |||||||||||||||||||
_____________________
(1)The carrying value for the Senior Notes is shown net of unamortized discount and unamortized deferred financing costs.
The carrying value reported for the Credit Facility approximates fair value because the underlying instruments are at interest rates which approximate current market rates. The fair value of the Senior Notes was determined utilizing a discounted cash flow approach.
(8) Equity Method Investment
RPC Power
RPC Power LLC ("RPC Power") is our power-focused joint venture with Conduit Power LLC, in which we have 50 % ownership. The Company is currently involved in two projects with RPC Power.
The first project provides a portion of our electric power needs for our field operations in our Champions field. This project consists of two sites located within the Company's operating area. The power generated and delivered by RPC Power is consumed by operating activities and not sold to the electric grid.
The second project is intended to provide power for the sale into ERCOT, the primary electric grid of Texas, with none of the generation consumed by Riley Permian. This project consists of four sites located outside of the Company's operating area, but in the west Texas region.
As the Company has significant influence due to our ownership percentage, but lacks control, RPC Power is accounted for as an equity method investment. In November 2024, the Company signed the Second Amendment to the A&R LLC Agreement, which increased the capital commitment for each owner from $42.5 million to $51.5 million. As of March 31, 2026, the Company had invested $43.5 million in the joint venture, comprised of $41.2 million in cash and $2.3 million of contributed assets, which was reduced by distributions and the Company's share of losses and increased by our share of income in the joint venture.
During the three months ended March 31, 2026, the Company contributed an additional $4.0 million to RPC Power. The Company has a remaining commitment to invest up to an additional $8.0 million, if required, to fund our portion of the future capital budget for the RPC Power joint venture. On December 31, 2025, RPC Power declared a $3 million dividend, of which $1.5 million was the Company's portion. The dividend was paid in January 2026.
See Note 9 - Transactions with Related Parties for further discussion of the contractual agreements between the Company and RPC Power and its affiliates and Note 15 - Commitments and Contingencies for additional information on future commitments.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
The following table presents the Company's equity method investment activity:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Equity method investment, beginning balance | $ | $ | |||||||||||||||||||||
| Contributions | |||||||||||||||||||||||
| Loss from equity method investment | ( | ( | |||||||||||||||||||||
Equity method investment, ending balance | $ | $ | |||||||||||||||||||||
(9) Transactions with Related Parties
RPC Power
In January 2023, the Company entered into a 10-year agreement with RPC Power, which provides for the conversion of specified quantities of the Company’s produced natural gas to electricity to power a portion of our oilfield operations in our Champions field ("Tolling Agreement"). The Tolling Agreement was amended and restated in June 2024 ("A&R Tolling Agreement") primarily to reflect the new in-service date of September 2024. The Company also entered into a 10-year agreement (“Asset Optimization Agreement”) in January 2023 that requires RPC Power to provide operational expertise on the implementation and management of the power generating assets subject to the A&R Tolling Agreement for a monthly fee of $20 thousand.
In May 2024, the Company entered into the Second Amended and Restated Limited Liability Company Agreement (“A&R LLC Agreement”) to expand the scope of our joint venture to include the constructing, owning and operating of additional new power generation and storage assets, for the sale of energy and ancillary services to ERCOT ("Merchant Deal").
In May 2024, the Company entered into a 10-year natural gas supply agreement ("Supply Agreement") with RPC Merchant LLC, a wholly owned subsidiary of RPC Power ("RPC Merchant"), to supply natural gas to fuel the natural gas generators under the Merchant Deal. The Company's commitment under the Supply Agreement is contingent upon project start-up which is expected to commence during the second half of 2026.
The Company incurred LOE from RPC Power of approximately $2.0 million and $1.6 million, respectively, for the three months ended March 31, 2026, and 2025. As of March 31, 2026, and December 31, 2025, the Company had approximately $0.7
See additional information related to RPC Power in Note 8 - Equity Method Investment and Note 15 - Commitments and Contingencies for additional information on future commitments.
Consulting and Legal Fees
The Company has an engagement agreement with di Santo Law PLLC ("di Santo Law"), a law firm owned by Beth di Santo, a member of our Board of Directors, pursuant to which di Santo Law's attorneys provide legal services to the Company.
The Company incurred legal fees from di Santo Law of approximately $0.3 million and $0.4 million for the three months ended March 31, 2026, and 2025, respectively. As of March 31, 2026, and December 31, 2025, the Company had approximately $1.8 million and $1.7 million, respectively, in amounts accrued for di Santo Law, which was included in other current liabilities in our accompanying condensed consolidated balance sheets.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
(10) Long-Term Debt
The following table summarizes the Company's outstanding debt:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
| Credit Facility | $ | $ | |||||||||
| Senior Notes | |||||||||||
| Principal | $ | $ | |||||||||
Less: Unamortized discount(1) | |||||||||||
Less: Unamortized deferred financing costs(1) | |||||||||||
| Total Senior Notes | $ | $ | |||||||||
Total debt | $ | $ | |||||||||
Less: Current portion of long-term debt(2) | |||||||||||
| Total long-term debt | $ | $ | |||||||||
(1)Unamortized discount and unamortized deferred financing costs are attributable to and amortized over the term of the Senior Notes.
(2)As of March 31, 2026, and December 31, 2025, the current portion of long-term debt reflects $20
Credit Facility
As of March 31, 2026, Riley Exploration - Permian, LLC ("REP LLC"), as borrower, and the Company, as parent guarantor, are parties to a credit agreement with Truist Bank and certain lenders party thereto, as amended, which provides for a Credit Facility with a borrowing base of $400 million. On December 13, 2024, the Company entered into the sixteenth amendment to the Credit Facility to, among other things, extend the stated maturity date from April 2026 to December 2028 (or if any Senior Notes are then outstanding, the date that is 181 days prior to the earliest stated maturity date of such Senior Notes, in this case October 2027) and increased the borrowing base from $375 million to $400 million, which was reaffirmed in December 2025 with the removal of the natural gas hedging requirement. Substantially all of the Company’s assets are pledged to secure the Credit Facility.
The Credit Facility contains certain covenants, which, among other things, require the maintenance of (i) a total leverage ratio of not greater than 3.00 to 1.00 and (ii) a minimum current ratio of not less than 1.0 to 1.0 as of the last day of any quarter. The Credit Facility also contains a total leverage ratio for the regulation of Restricted Payments, as defined in the credit agreement after giving pro forma effect to such Restricted Payments, which includes payments to any holder of the Company's shares, would not exceed 2.50 to 1.00. If the Company's leverage ratio, after giving pro forma effect to such Restricted Payments (as defined in the Credit Agreement), is above 2.0 to 1.0, then an additional test of free cash flow is applied, and the Company will only be permitted to make such Restricted Payments if such payment does not exceed the Company's free cash flow. In addition to and after giving effect to such Restricted Payments, the availability of funds under the Company's Credit Facility must be greater than or equal to 20 % of the elected commitments. The Company must maintain a minimum hedging requirement for oil based on our proved developed producing projected volumes on a rolling 24-month basis.
The following table summarizes the Credit Facility balances:
| March 31, 2026 | December 31, 2025 | ||||||||||
| (In thousands) | |||||||||||
| Outstanding borrowings | $ | $ | |||||||||
| Available under the borrowing base | $ | $ | |||||||||
See additional information regarding the Credit Facility in Note 16 - Subsequent Events.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Senior Notes
On April 3, 2023, the Company (as issuer) completed our issuance of $200 million aggregate principal amount of 10.50 % senior unsecured notes with final maturity in April 2028 pursuant to a note purchase agreement (the "Note Purchase Agreement"), with the Senior Notes issued at a 6 % discount.
Interest is due and payable at the end of each quarter. In addition to interest, the Company will repay 2.50 % of the original principal amount each quarter resulting in $5 million quarterly principal payments until the maturity of the Senior Notes. As of March 31, 2026, the Company had $20 million in current liabilities in our accompanying condensed consolidated balance sheets related to the quarterly principal payments due within the next 12 months.
The Company may, at our option, redeem, at any time and from time to time on or prior to April 3, 2026, some or all of the Senior Notes at 100 % of the principal amount thereof plus the make-whole amount plus a premium of 5.25 % as set forth in the Note Purchase Agreement plus accrued and unpaid interest, if any. After April 3, 2026, but on or prior to October 3, 2026, the Company may, at our option, redeem, at any time and from time to time some or all of the Senior Notes at 100 % of the principal amount thereof plus a premium of 5.25 % as set forth in the Note Purchase Agreement plus accrued and unpaid interest, if any. After October 3, 2026, the Company may redeem some or all of the Senior Notes at 100 % of the principal amount thereof plus accrued and unpaid interest, if any. The principal remaining outstanding at the time of maturity is required to be paid in full by the Company. Certain note features, including those discussed above, were evaluated and deemed to be remote. Due to the remote nature, the fair value of these features was estimated to be approximately zero.
The Senior Notes contain certain covenants, which, among other things, require the maintenance of (i) a total leverage ratio of not greater than 3.00 to 1.00 and (ii) an asset coverage ratio greater than 1.50 to 1.00. The Senior Notes also contain a total leverage ratio and an asset coverage ratio for Restricted Payments, as defined in the Note Purchase Agreement. The leverage ratio, after giving pro forma effect to such Restricted Payments, cannot exceed 2.00 to 1.00, and the asset coverage ratio, after giving effect to such Restricted Payments, must be greater than or equal to 1.50 to 1.00. In addition to and after giving effect to such Restricted Payments, the availability of funds under the Company's Credit Facility must be greater than or equal to 15 % of the Aggregate Elected Commitment Amount, as defined in the Note Purchase Agreement. Upon issuance of the Senior Notes, the Company must maintain a minimum hedging requirement included within the Senior Notes for oil and natural gas based on our proved developed producing projected volumes for oil and natural gas on a rolling 18-month basis.
The Senior Notes are general unsecured obligations ranking equally in right of payment with all other senior unsecured indebtedness of the Company and are senior in right of payment to all existing and future subordinated indebtedness of the Company. The Note Purchase Agreement contains customary terms and covenants, including limitations on the Company’s ability to incur additional secured and unsecured indebtedness.
The following table summarizes the Company's interest expense:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Interest expense | $ | $ | |||||||||||||||||||||
Interest income | ( | ( | |||||||||||||||||||||
| Capitalized interest | ( | ( | |||||||||||||||||||||
| Amortization of deferred financing costs | |||||||||||||||||||||||
| Amortization of discount on Senior Notes | |||||||||||||||||||||||
| Unused commitment fees on Credit Facility | |||||||||||||||||||||||
| Total interest expense, net | $ | $ | |||||||||||||||||||||
During the three months ended March 31, 2026, and 2025, the weighted average interest rate on the Credit Facility was 6.53 % and 7.25 %, respectively.
As of March 31, 2026, the Senior Notes had $4.5 million of unamortized discount and $1.8 million of unamortized deferred financing costs, resulting in an effective interest rate of 13.4 % during the three months ended March 31, 2026. As of December
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
31, 2025, the Senior Notes had $5.1 million of unamortized discount and $2.1 million of unamortized deferred financing costs, resulting in an effective interest rate of 13.4 % during the year ended December 31, 2025.
As of March 31, 2026, the Company was in compliance with all covenants contained in the Credit Agreement and Note Purchase Agreement.
(11) Shareholders' Equity
Dividends
For the three months ended March 31, 2026, and 2025, the Company declared quarterly dividends on our common stock totaling approximately $8.6 million and $8.2 million, respectively.
Stock-Based Compensation
In April 2023, at the Company's annual meeting of stockholders, the Company's stockholders approved the Amended and Restated 2021 Long Term Incentive Plan (the "A&R LTIP") which authorized up to 2,337,022 shares of common stock that may be granted as awards under the A&R LTIP. As of March 31, 2026, the A&R LTIP had 345,122 shares remaining that are available for future awards.
In March 2025, the Company introduced performance-based restricted stock awards to further align the compensation of the Company's executive officers with the long-term growth of the Company and the interests of its shareholders. Performance stock awards may be earned based on the Company’s achievement of total shareholder return ("TSR") relative to its peer group during the applicable three-year performance period. Payouts for the executive officers can range from 0 % to 200 % of the target and have cliff-vesting after three years , with dividends paid on the number of shares vested. As a result, the Company has reduced the remaining shares available to be granted as awards under the A&R LTIP by 168,406 shares (the full 200 %), which assumes the highest percentage payout for the performance stock awards. The number of unvested shares of performance restricted stock used to calculate our fully diluted shares based on the Company's relative TSR ranking as of March 31, 2026, and December 31, 2025, is 122,936 and 149,039 , respectively.
There were no performance stock awards granted during the three months ended March 31, 2026. During the three months ended March 31, 2025, the fair value of performance awards were estimated as of the date of grant using a Monte Carlo simulation with the following assumptions:
Grant-date fair value | $ | ||||
Risk-free interest rate | |||||
Volatility factor | |||||
2021 Long-Term Incentive Plan
The following table presents the Company's restricted stock activity during the three months ended March 31, 2026, under the A&R LTIP:
| Restricted Stock Awards | ||||||||||||||
| Shares | Weighted Average Grant Date Fair Value | |||||||||||||
Unvested at December 31, 2025 | $ | |||||||||||||
| Granted | $ | |||||||||||||
| Vested | ( | $ | ||||||||||||
| Forfeited | ( | $ | ||||||||||||
Unvested at March 31, 2026 | $ | |||||||||||||
For the three months ended March 31, 2026, and 2025, the total stock-based compensation expense was $2.3 million and $1.4 million, respectively. Stock-based compensation expense is included in general and administrative costs in the Company's accompanying condensed consolidated statements of operations for the restricted stock awards granted under the A&R LTIP.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
The following table presents unrecognized stock-based compensation expense expected to be recognized and the related weighted average recognition period associated with unvested shares as of March 31, 2026:
Restricted Stock Awards | Performance Stock Awards | ||||||||||
Unrecognized compensation expense (in millions) | $ | $ | |||||||||
Weighted average period for recognition (months) | |||||||||||
Share Repurchases
In December 2025, our Board of Directors approved a stock repurchase program (the “Repurchase Program”) authorizing the repurchase of up to $100 million of our common stock from time to time over a period of 24 months, including through open market purchases, through block trades, in privately negotiated transactions, or by other means, including through the use of trading plans, each in accordance with applicable securities laws and other restrictions. The Repurchase Program does not obligate us to purchase any common stock and may be suspended from time to time, modified, extended or discontinued by the Board at any time. Under the Repurchase Program, 152,408 shares were purchased and subsequently retired during the three months ended March 31, 2026. The remaining repurchase authority under the Repurchase Program at March 31, 2026, was $96 million.
(12) Income Taxes
The components of the Company's consolidated provision for income taxes from operations are as follows:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
Current income tax expense: | |||||||||||||||||||||||
| Federal | $ | $ | |||||||||||||||||||||
| State | |||||||||||||||||||||||
Total current income tax expense | $ | $ | |||||||||||||||||||||
Deferred income tax benefit: | |||||||||||||||||||||||
| Federal | $ | ( | $ | ( | |||||||||||||||||||
| State | ( | ( | |||||||||||||||||||||
Total deferred income tax benefit | $ | ( | $ | ( | |||||||||||||||||||
Total income tax (benefit) expense | $ | ( | $ | ||||||||||||||||||||
Beginning in the first quarter of 2026, the Company elected to change its interim income tax reporting methodology from the income statement method to the balance sheet method and will apply this method consistently for the remainder of the fiscal year. The change was made because significant unrealized losses on derivative instruments recognized during the three months ended March 31, 2026 are expected to reverse in future periods, and use of the income statement method would have caused a disproportionate amount of the related tax benefit to be recognized in the first quarter. Under the balance sheet method, interim income tax expense is based on changes in deferred tax assets and liabilities during the period, which the Company believes more appropriately reflects the allocation of the annual effective tax rate between current and deferred income tax expense. This change affects only the allocation of the interim income tax expense between current and deferred income tax expense and does not affect the Company’s full-year effective tax rate or total quarterly income tax expense.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
A reconciliation of the statutory federal income tax rate to the Company's effective income tax rate is as follows:
| Three Months Ended March 31, | |||||||||||||||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||||||||||||||
| Amount | Percent | Amount | Percent | ||||||||||||||||||||||||||||||||
(In thousands, except percentages) | |||||||||||||||||||||||||||||||||||
U.S federal statutory tax rate | $ | ( | % | $ | % | ||||||||||||||||||||||||||||||
State income taxes, net of federal income tax effect(1) | ( | % | % | ||||||||||||||||||||||||||||||||
Nondeductible items: | |||||||||||||||||||||||||||||||||||
Nondeductible compensation | ( | % | % | ||||||||||||||||||||||||||||||||
Stock-based compensation | ( | % | ( | % | |||||||||||||||||||||||||||||||
| Other | ( | % | % | ||||||||||||||||||||||||||||||||
| Effective income tax rate | $ | ( | % | $ | % | ||||||||||||||||||||||||||||||
_____________________
(1)State taxes in New Mexico and Texas make up the tax effect in this category.
Cash paid for income taxes was as follows:
| Three Months Ended March 31, | |||||||||||||||||
| 2026 | 2025 | ||||||||||||||||
| (In thousands) | |||||||||||||||||
Total federal | $ | $ | |||||||||||||||
Total state and local | |||||||||||||||||
Total income taxes paid | $ | $ | |||||||||||||||
The Company's federal income tax returns for the years subsequent to December 31, 2021, remain subject to examination. The Company's income tax returns in major state income tax jurisdictions remain subject to examination for various periods subsequent to December 31, 2020. The Company currently believes that all other significant filing positions are highly certain and that all of our other significant income tax positions and deductions would be sustained under audit or the final resolution would not have a material effect on our consolidated financial statements. Therefore, the Company has not established any reserves for uncertain tax positions.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
(13) Net Income Per Share
The Company calculated net income per share using the treasury stock method. The table below sets forth the computation of basic and diluted net income per share:
| Three Months Ended March 31, | ||||||||||||||||||||||||||
| 2026 | 2025 | |||||||||||||||||||||||||
(In thousands, except per share amounts) | ||||||||||||||||||||||||||
Net income (loss) | $ | ( | $ | |||||||||||||||||||||||
| Basic weighted average common shares outstanding | ||||||||||||||||||||||||||
| Restricted shares | ||||||||||||||||||||||||||
| Diluted weighted average common shares outstanding | ||||||||||||||||||||||||||
Basic net income (loss) per share | $ | ( | $ | |||||||||||||||||||||||
Diluted net income (loss) per share | $ | ( | $ | |||||||||||||||||||||||
The following shares were excluded from the calculation of diluted net income per share due to their anti-dilutive effect:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| (In thousands) | |||||||||||||||||||||||
| Restricted shares | |||||||||||||||||||||||
(14) Segments
The Company’s oil and gas exploration and production activities are solely focused in the U.S. For financial reporting purposes, the Company aggregates our operating segments into one
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
The following table presents consolidated net income, the significant measure of profit and loss used by the CODM, as well as total assets, capital expenditures and our equity method investment for the Company's single reportable segment:
| Three Months Ended March 31, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
(In thousands) | |||||||||||||||||||||||
Total Revenues | $ | $ | |||||||||||||||||||||
| Less: | |||||||||||||||||||||||
Lease operating expenses | |||||||||||||||||||||||
Production and ad valorem taxes | |||||||||||||||||||||||
Exploration costs | |||||||||||||||||||||||
Depletion, depreciation, amortization and accretion | |||||||||||||||||||||||
Administrative Costs | |||||||||||||||||||||||
Stock-based compensation expense | |||||||||||||||||||||||
Interest expense, net of capitalized interest(1) | |||||||||||||||||||||||
Interest income | ( | ( | |||||||||||||||||||||
| Loss on derivatives, net | |||||||||||||||||||||||
| Loss from equity method investment | |||||||||||||||||||||||
Loss on acquisitions and divestitures, net | |||||||||||||||||||||||
Income tax (benefit) expense | ( | ||||||||||||||||||||||
Segment net income (loss)(2) | $ | ( | $ | ||||||||||||||||||||
| Total assets | $ | $ | |||||||||||||||||||||
Capital expenditures(3) | $ | $ | |||||||||||||||||||||
| Equity method investment | $ | $ | |||||||||||||||||||||
_____________________
(1)Interest expense is shown gross of or prior to the effect of interest income.
(2)There are no reconciling items between net income (loss) presented in our accompanying condensed consolidated statements of operations and segment net income (loss).
(3)Capital expenditures are accrual (activity-based) before acquisitions.
(15) Commitments and Contingencies
Legal Matters
Due to the nature of the Company's business, the Company may at times be subject to claims and legal actions. The Company accrues liabilities when it is probable that future costs will be incurred, and such costs can be reasonably estimated. Such accruals are based on developments to date and the Company’s estimates of the outcomes of these matters. The Company did not recognize any material liability for legal matters as of March 31, 2026, or December 31, 2025. Management believes it is remote that the impact of such matters will have a materially adverse effect on the Company’s financial position, results of operations, or cash flows.
Environmental Matters
The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. These laws, which are often changing, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. The Company had no
Contractual Commitments
The Company is a party to a gas gathering, treating and processing agreement with Targa Northern Delaware LLC ("Targa") in Texas. Under the terms of the agreement, the Company agreed to deliver an annual minimum volume during the contract term. As of March 31, 2026, approximately five years remain under this contract.
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RILEY EXPLORATION PERMIAN, INC.
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Under the A&R Tolling Agreement with RPC Power, the Company has committed to provide specified quantities of our natural gas for 10 years following the in-service date of September 2024, for a fee based on a per MMBtu basis adjusted for contractual usage factors. The Company also entered into the Asset Optimization Agreement that requires RPC Power to provide operational expertise on the implementation and management of the power generating assets subject to the A&R Tolling Agreement for a monthly fee of $20 thousand.
Under the Supply Agreement with RPC Merchant, the Company agreed to supply natural gas to fuel the natural gas generators under the Merchant Deal for 10 years. The Company's commitment under the Supply Agreement is contingent upon project start-up which is expected to commence during the second half of 2026.
Under the A&R LLC Agreement with RPC Power, the Company agreed to make additional capital contributions to fund its portion of the capital budget for RPC Power. The Company's remaining commitment, if required, is $8.0 million.
See Note 8 - Equity Method Investment and Note 9 - Transactions with Related Parties for additional information related to RPC Power.
Midstream Gas Purchase Agreement
On December 31, 2024, the Company signed a long-term gas purchase agreement for the Company's New Mexico field with Targa, which was amended and restated ("the A&R Gas Purchase Agreement") in connection with the Company's December 2025 sale of Dovetail Midstream, LLC, a wholly owned subsidiary of the Company that holds certain midstream infrastructure projects in Eddy County, New Mexico, to Targa. The agreement has a minimum volume commitment in New Mexico for an initial 15-year term from the in-service date, which is expected to commence before the end of 2026.
Waterbridge
On January 6, 2026, the Company entered into a 15-year water management services agreement ("Waterbridge Agreement") with Waterbridge Stateline LLC ("Waterbridge") to deliver a portion of its New Mexico produced water for disposal purposes within a specified dedicated area. During the first 7 years of the agreement, the Company has both annual and a cumulative volume commitment to deliver minimum quantities of produced water. The in-service date is expected to be September 2026.
(16) Subsequent Events
Dividend Declaration
On April 15, 2026, the Board of Directors of the Company declared a cash dividend of $0.40
Credit Facility Redetermination
On April 30, 2026, in connection with the semi‑annual redetermination process under the Company’s Credit Facility, the Company entered into the eighteenth amendment to the Credit Facility, which among other things, increased the Company’s borrowing base from $400 million to $425 million and documented the Company's election to maintain commitments thereunder at $400 million. In addition, the eighteenth amendment shortens the springing maturity of the Credit Facility in advance of the Senior Notes from 181 days to 91 days, effectively extending the maturity date for the Credit Facility to January 2028, given the April 2028 stated maturity of the Senior Notes. All other significant terms of the Credit Facility remained unchanged. The Company was in compliance with all covenants under the Credit Facility as of March 31, 2026.
Equity Investment Contribution
30
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Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of the Company’s financial condition and results of operations should be read in conjunction with the Company's condensed consolidated financial statements and related notes thereto presented in this report as well as the Company's audited consolidated financial statements and related notes included in the Company's Annual Report for the fiscal year ended December 31, 2025. The following discussion contains "forward-looking statements" that reflect the Company’s future plans, estimates, beliefs and expected performance. The Company’s actual results could differ materially from those discussed in these forward-looking statements. See "Cautionary Statement Regarding Forward-Looking Statements" and "Part II, Item 1A. Risk Factors" below and the information set forth in the Risk Factors under Part I, Item 1A of the Company's Annual Report for the fiscal year ended December 31, 2025.
Overview
Riley Permian is a growth-oriented, independent oil and natural gas company focused on horizontal drilling of conventional oil-saturated and liquids-rich formations in the Permian Basin that produce long-term cash flows. The majority of our acreage is located in Yoakum County, Texas and Eddy County, New Mexico.
Our strategic business objectives include enhancing the rate of return on our invested capital, generating sustainable free cash flow, maintaining a strong and flexible balance sheet and maximizing returns to shareholders. We implement this strategy primarily through identification and capture of attractive development opportunities, optimization of our assets and pursuing complementary growth opportunities that increase our scale and meet our strategic and financial objectives.
Recent Developments
Geopolitical and Economic Conditions
Commodity prices remain volatile. General domestic and international economic, market and political conditions, including military conflicts, global economic growth, unpredictability of tariffs, actions of OPEC+ countries, and changes to the current political environment could prolong market volatility and cause a decline in commodity prices.
We monitor the risk of cost pressures in specific areas of our operating expenses and capital expenditures. Our margins may be compressed if costs increase more than commodity prices and our revenues, net of derivatives. Additionally, the current interest rate environment remains sensitive to shifts in macroeconomic factors and central bank policies. Increased interest rates could have the effects of raising our cost of capital and the potential for depressing economic growth, either of which (or the combination thereof) could hurt the financial and operating results of our business.
The Company cannot estimate the length or gravity of the future impact these conditions will have on the Company's results of operations, financial position, liquidity and the value of the oil and natural gas reserves.
Midstream Disruption
Beginning on March 28, 2026, and continuing subsequent to the balance sheet date, an unplanned outage at a third-party gas processing facility in New Mexico operated by one of our midstream counterparties required us to shut in a significant portion of our New Mexico production. The duration of the outage remains uncertain; however, the impact on the three months ended March 31, 2026 was not material.
Based on the limited geographic scope of affected production, the continued strong performance of our Texas operations, and our reallocation of capital to accelerated drilling and completion activity in Texas, we do not currently expect the outage to have a material impact on our second quarter or full-year 2026 production volumes, revenues, or results of operations.
We expect our reliance on this counterparty to diminish once additional processing and takeaway capacity becomes available from the new high-pressure gathering and trunk line infrastructure currently being constructed by Targa in Eddy County, New Mexico under the A&R Gas Purchase Agreement. See Note 15 – Commitments and Contingencies for further discussion of the Gas Purchase Agreement. The in-service date of the new Targa pipeline system is currently expected to occur before the end of 2026. We will continue to monitor the situation.
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Results of Operations
Comparison for the three months ended March 31, 2026, and 2025:
| Three Months Ended March 31, | ||||||||||||||
| 2026 | 2025 | |||||||||||||
Revenues (in thousands):(1) | ||||||||||||||
Oil sales, net | $ | 124,968 | $ | 98,592 | ||||||||||
Natural gas sales, net | (6,359) | 1,584 | ||||||||||||
NGL sales, net | (4,728) | 2,281 | ||||||||||||
| Oil and natural gas sales, net | $ | 113,881 | $ | 102,457 | ||||||||||
| Production Data, net: | ||||||||||||||
| Oil (MBbls) | 1,814 | 1,406 | ||||||||||||
| Natural gas (MMcf) | 3,781 | 2,228 | ||||||||||||
| NGLs (MBbls) | 760 | 422 | ||||||||||||
Total equivalent (MBoe) | 3,204 | 2,199 | ||||||||||||
Daily equivalent production (Boe/d) | 35,600 | 24,433 | ||||||||||||
Daily oil production (Bbls/d) | 20,156 | 15,622 | ||||||||||||
Average Realized Prices:(1) | ||||||||||||||
| Oil ($ per Bbl) | $ | 68.89 | $ | 70.12 | ||||||||||
| Natural gas ($ per Mcf) | $ | (1.68) | $ | 0.71 | ||||||||||
| NGLs ($ per Bbl) | $ | (6.22) | $ | 5.41 | ||||||||||
Average Realized Prices, including the effect of derivative settlements:(1)(2) | ||||||||||||||
| Oil ($ per Bbl) | $ | 62.40 | $ | 70.97 | ||||||||||
| Natural gas ($ per Mcf) | $ | (1.67) | $ | 0.68 | ||||||||||
NGLs ($ per Bbl)(3) | $ | (6.22) | $ | 5.41 | ||||||||||
_____________________
(1)The Company's oil, natural gas and NGL sales are presented net of GP&T costs. These costs, related to natural gas and NGLs, at times exceeded the price received and resulted in negative average realized prices.
(2)The Company's calculation of the effects of derivative settlements includes gains (losses) on the settlement of our commodity derivative contracts. These realized gains (losses), along with unrealized gains (losses) from changes in the fair value of derivatives, are included under other expense on the Company’s condensed consolidated statements of operations.
(3)During the periods presented, the Company did not have any NGL derivative contracts in place.
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Oil and Natural Gas Revenues
Our revenues are derived from the sale of our oil and natural gas production, including the sale of NGLs that are extracted from our natural gas during processing. Realized prices and revenues from product sales are a function of the volumes produced, product quality, market prices, gas Btu content, as well as GP&T costs. GP&T costs are allocated across natural gas and NGLs based on revenue, which leads to heightened fluctuations in such cost allocations across periods. Our revenues from oil, natural gas and NGL sales do not include the effects of derivatives. Our revenues may vary significantly from period to period as a result of changes in the volume of production sold or changes in commodity prices. The following table presents the Company's oil and natural gas sales prior to and net of GP&T costs:
| Three Months Ended March 31, | ||||||||||||||
| 2026 | 2025 | |||||||||||||
Revenues: | (In thousands) | |||||||||||||
| Oil sales, net | $ | 124,968 | $ | 98,592 | ||||||||||
Gas sales | $ | (3,432) | $ | 4,480 | ||||||||||
| Less: GP&T costs | (2,927) | (2,896) | ||||||||||||
Gas sales, net | $ | (6,359) | $ | 1,584 | ||||||||||
NGL sales | $ | 12,861 | $ | 10,226 | ||||||||||
| Less: GP&T costs | (17,589) | (7,945) | ||||||||||||
NGL sales, net | $ | (4,728) | $ | 2,281 | ||||||||||
Oil and natural gas sales | $ | 134,397 | $ | 113,298 | ||||||||||
| Less: GP&T costs | (20,516) | (10,841) | ||||||||||||
Oil and natural gas sales, net | $ | 113,881 | $ | 102,457 | ||||||||||
Three months ended March 31, 2026, compared to three months ended March 31, 2025
The Company’s total oil and natural gas sales, net increased $11.4 million, or 11%. The following tables summarize the effects of price, volume and GP&T cost changes on our revenues from oil, natural gas and NGLs:
Oil revenues
Oil revenues increased by $26.4 million, as higher volumes more than offset the impact of lower prices. Oil production volume increased by 29% from wells acquired in the Silverback Acquisition and new wells turned to sales. Realized oil price decreased by $1.23 per Bbl, as lower West Texas Sour pricing more than offset a $0.96 increase in the average WTI price.
(In thousands) | ||||||||
Oil sales, net for the three months ended March 31, 2025 | $ | 98,592 | ||||||
Price | (2,234) | |||||||
Volume | 28,610 | |||||||
Oil sales, net for the three months ended March 31, 2026 | $ | 124,968 | ||||||
Natural gas revenues
Natural gas revenues decreased by $7.9 million, as lower prices and higher GP&T costs more than offset higher volumes. Despite a $0.57 per Mcf increase in the average Henry Hub price, realized natural gas prices before GP&T costs decreased by $2.92, which was the result of an increase in the negative basis differentials due to regional pipeline constraints. Natural gas
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production volumes increased by 70% due to acquired wells from the Silverback Acquisition, increased processing capacity from our midstream partner in our Champions field and new wells turned to sales.
(In thousands) | ||||||||
Gas sales, net for the three months ended March 31, 2025 | $ | 1,584 | ||||||
Price | (11,035) | |||||||
Volume | 3,123 | |||||||
| GP&T costs | (31) | |||||||
Gas sales, net for the three months ended March 31, 2026 | $ | (6,359) | ||||||
NGL revenues
NGL revenues decreased by $7.0 million, as lower prices and higher GP&T costs more than offset higher volumes. Realized NGL prices before GP&T costs decreased by $7.31 per Bbl, primarily due to lower Mont Belvieu pricing. Higher GP&T costs resulted from increased volumes, as well as from higher allocations of the GP&T costs from lower realized natural gas revenues before GP&T costs. NGL production volumes increased 80% due to new wells turned to sales, increased processing capacity from our midstream partner in our Champions field and from wells acquired in the Silverback Acquisition.
(In thousands) | |||||
NGL sales, net for the three months ended March 31, 2025 | $ | 2,281 | |||
Price | (5,555) | ||||
Volume | 8,190 | ||||
| GP&T costs | (9,644) | ||||
NGL sales, net for the three months ended March 31, 2026 | $ | (4,728) | |||
Costs and Expenses
The following table presents the Company's operating costs and expenses and other expenses:
| Three Months Ended March 31, | |||||||||||
| 2026 | 2025 | ||||||||||
| Costs and Expenses: | (In thousands) | ||||||||||
| Lease operating expenses | $ | 24,071 | $ | 18,331 | |||||||
| Production and ad valorem taxes | $ | 9,032 | $ | 6,670 | |||||||
| Exploration costs | $ | 967 | $ | 9 | |||||||
| Depletion, depreciation, amortization and accretion | $ | 25,720 | $ | 19,138 | |||||||
| Administrative costs | $ | 8,120 | $ | 7,438 | |||||||
Stock-based compensation | 2,301 | 1,369 | |||||||||
| General and administrative expense | $ | 10,421 | $ | 8,807 | |||||||
| Interest expense, net | $ | 6,357 | $ | 6,661 | |||||||
| Loss on derivatives, net | $ | 126,970 | $ | 5,850 | |||||||
| Loss from equity method investment | $ | 368 | $ | 119 | |||||||
Loss on acquisitions and divestitures, net | $ | 2,697 | $ | — | |||||||
| Income tax (benefit) expense | $ | (22,288) | $ | 8,239 | |||||||
Lease Operating Expenses ("LOE")
LOE are the costs incurred in the operation and maintenance of producing properties. Expenses for electricity, compression, direct labor, saltwater disposal and materials and supplies comprise the most significant portion of our lease operating expenses. Certain operating cost components, such as direct labor and materials and supplies, generally remain relatively fixed across broad production volume ranges, but can fluctuate depending on activities performed during a specific
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period. For instance, repairs to our pumping equipment or surface facilities or subsurface maintenance result in increased production expenses in periods during which they are performed. Certain operating cost components, such as saltwater disposal associated with produced water, are variable and increase or decrease as hydrocarbon production levels and the volume of water disposal increases or decreases.
The Company’s LOE increased by $5.7 million for the three months ended March 31, 2026, compared to the three months ended March 31, 2025. The LOE increase of approximately $4.5 million and workover expense increase of approximately $1.2 million were driven primarily by the Silverback Acquisition. The LOE increase was due to higher field payroll and other variable costs driven by increased production volumes.
Production and Ad Valorem Tax Expense
Production taxes are paid on produced oil, natural gas and NGLs based on a percentage of revenues at fixed rates established by federal, state or local taxing authorities. In general, the production taxes we pay correlate to changes in our oil, natural gas and NGL revenues. We are also subject to ad valorem taxes in the counties where our production is located. Ad valorem taxes are generally based on the valuation of our oil and natural gas properties, which also trend with oil and natural gas prices and vary across the different counties in which we operate.
Production and ad valorem taxes increased by $2.4 million for the three months ended March 31, 2026, compared to the three months ended March 31, 2025, primarily due to increased production in both our Champions and Red Lake fields, with higher production in Red Lake due to the Silverback Acquisition, and an increase in crude oil prices, as well as the reversal of a previously accrued liability related to the Environmental Protection Agency’s waste emission charge that was nullified in the first quarter of 2025.
Depletion, Depreciation, Amortization and Accretion ("DD&A") Expense
DD&A expense is the systematic expensing of the capitalized costs incurred to acquire, explore and develop oil, natural gas and NGLs. All costs incurred in the acquisition, exploration and development of properties (excluding costs of surrendered and abandoned leaseholds, delay lease rentals, dry holes and overhead related to exploration activities) are capitalized. Capitalized costs are depleted using the units of production method.
Accretion expense relates to ARO. We record the fair value of the liability for ARO in the period in which the liability is incurred (at the time the wells are drilled or acquired) with the offset to property cost. The liability accretes each period until it is settled or the well is sold, at which time the liability is removed.
The following table presents the components of the Company's DD&A expense:
| Three Months Ended March 31, | |||||||||||
| 2026 | 2025 | ||||||||||
| (In thousands) | |||||||||||
| Depletion | $ | 24,784 | $ | 17,557 | |||||||
| Accretion | 766 | 1,374 | |||||||||
Depreciation and amortization | 170 | 207 | |||||||||
Total DD&A expense | $ | 25,720 | $ | 19,138 | |||||||
DD&A expense increased by $6.6 million for the three months ended March 31, 2026, compared to the three months ended March 31, 2025, primarily due to higher production volumes, which increased depletion expense by approximately $5.7 million, in addition to the inclusion of the Silverback Acquisition, which increased depletion expense by approximately $3.5 million. These increases were partially offset by a lower depletion rate in our Red Lake field, which decreased depletion expense by approximately $2.6 million due to reserve estimate revisions.
General and Administrative ("G&A") Expense
G&A expenses consist of administrative costs and stock-based compensation expense. Administrative costs include corporate overhead such as payroll and benefits for our staff, office costs, fees for professional services such as audit and legal services, technology costs, insurance and other. Stock-based compensation expense reflects costs associated with our stock granted to employees and members of our board of directors. G&A expenses are reported net of overhead recoveries.
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Total G&A expense increased by $1.6 million for the three months ended March 31, 2026, compared to the three months ended March 31, 2025. Administrative costs increased by $0.7 million primarily due to increased employee headcount. Stock-based compensation expensed increased by $0.9 million due to an increase in outstanding equity awards.
Interest Expense, net
Interest expense, net decreased by $0.3 million for the three months ended March 31, 2026, compared to the three months ended March 31, 2025, primarily due to a lower total debt balance along with lower interest rates on borrowings under our Credit Facility.
Loss on Derivatives, net
The Company recognizes settlements and changes in the fair value of our derivative contracts as a single component within other expense in our condensed consolidated statements of operations. We have oil and natural gas derivative contracts, including fixed price swaps, basis swaps and collars, that settle against various indices. The following table presents the components of the Company's loss on derivatives, net:
| Three Months Ended March 31, | |||||||||||
| 2026 | 2025 | ||||||||||
| (In thousands) | |||||||||||
| Settlements on derivative contracts | $ | (11,725) | $ | 1,115 | |||||||
| Non-cash loss on derivatives | (115,245) | (6,965) | |||||||||
| Loss on derivatives, net | $ | (126,970) | $ | (5,850) | |||||||
Cash gains or losses on settled derivative contracts relate to contracts that settle during the period and are a function of the difference in settled versus contractual prices and the associated hedged volumes for each underlying commodity. Non-cash gains or losses on derivatives relate to unsettled contracts and are a function of changes in derivative fair values associated with fluctuations in the forward price curves for the commodities relative to contractual pricing and the associated hedged volumes for each underlying commodity for our derivative contracts outstanding.
Income Tax (Benefit) Expense
Current income taxes represent the amount the Company expects to owe to federal and state tax authorities in the current period, based on our taxable income. Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates. See Note 12 - Income Taxes for further discussion of income taxes. Total income tax (benefit) expense is summarized below:
| Three Months Ended March 31, | |||||||||||
| 2026 | 2025 | ||||||||||
| (In thousands) | |||||||||||
| Current income tax expense | $ | 1,020 | $ | 10,065 | |||||||
Deferred income tax benefit | (23,308) | (1,826) | |||||||||
Total income tax (benefit) expense | $ | (22,288) | $ | 8,239 | |||||||
| Effective income tax rate | 24.0% | 23.9% | |||||||||
The decrease in current income tax expense was primarily attributable to higher capital spending during the three months ended March 31, 2026, compared to the three months ended March 31, 2025. The deferred income tax benefit increased primarily due to a higher non-cash loss on derivatives over the same period.
Liquidity and Capital Resources
The business of exploring for, developing and producing oil and natural gas is capital intensive. Because oil, natural gas and NGL reserves are a depleting resource, we must make capital investments, like all upstream operators, to sustain and grow production. The Company’s principal liquidity requirements are to finance our operations, fund capital expenditures, fund acquisitions and joint venture commitments, pay dividends and satisfy any indebtedness obligations. Cash flows are subject to a number of variables, including the level of oil and natural gas production and prices, and the significant capital expenditures
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required to more fully develop the Company’s oil and natural gas properties. Historically, our primary sources of capital funding and liquidity have been our cash on hand, cash flow from operations, borrowings under our Credit Facility and the issuance of our Senior Notes. At times and as needed, we may also issue debt or equity securities, including through transactions under our shelf registration statement filed with the SEC. We estimate the combination of the sources of capital discussed above will continue to be adequate to meet our short and long-term liquidity needs.
Cash on hand and operating cash flow can be subject to fluctuations due to trends and uncertainties that are beyond our control. Likewise, our ability to issue equity, debt and obtain credit facilities on favorable terms may be impacted by a variety of market factors as well as fluctuations in our results of operations.
For further discussion of risks related to our liquidity and capital resources, see "Item 1A. Risk Factors."
Working Capital
Working capital represents the funds available to meet day-to-day operational needs and is the difference in our current assets and our current liabilities. Working capital is an indication of liquidity and potential need for short-term funding. The change in our working capital requirements is driven generally by changes in accounts receivable, accounts payable, commodity prices, credit extended to, and the timing of collections from customers, the level and timing of spending for expansion activity, and the timing of debt maturities. Our working capital fluctuates as our drilling and completion activity changes with periods of higher and lower activity. We utilize our Credit Facility and cash on hand to manage the timing of cash flows and fund short-term working capital deficits. At March 31, 2026, we had $293 million of undrawn capacity under our Credit Facility. The following table presents the components of working capital:
| Three Months Ended March 31, | ||||||||||||||
| 2026 | 2025 | |||||||||||||
| (In thousands) | ||||||||||||||
| Current Assets: | ||||||||||||||
| Cash | $ | 15,809 | $ | 8,857 | ||||||||||
| Accounts receivable, net | 56,629 | 37,518 | ||||||||||||
| Prepaid expenses | 2,710 | 1,838 | ||||||||||||
| Inventory | 7,919 | 4,346 | ||||||||||||
| Current derivative assets | — | 1,253 | ||||||||||||
| Total Current Assets | $ | 83,067 | $ | 53,812 | ||||||||||
Current Liabilities: | ||||||||||||||
| Accounts payable | $ | 22,716 | $ | 18,134 | ||||||||||
| Accrued liabilities | 44,377 | 31,588 | ||||||||||||
| Revenue payable | 57,186 | 34,161 | ||||||||||||
| Current derivative liabilities | 77,937 | 2,659 | ||||||||||||
| Current portion of long-term debt | 20,000 | 20,000 | ||||||||||||
| Other current liabilities | 41,439 | 15,292 | ||||||||||||
| Total Current Liabilities | $ | 263,655 | $ | 121,834 | ||||||||||
Working Capital Deficit | $ | (180,588) | $ | (68,022) | ||||||||||
Our working capital deficit increased by $113 million primarily due to a $75 million increase in current derivative liabilities for our unrealized positions due to the increased crude oil pricing, an increase of $11 million related to prepayments from partners and a $4.5 million increase in the current liability for the earnout payments related to the Silverback Acquisition, both of which are included in other current liabilities. Excluding the impact of derivatives, the increased working capital deficit corresponds with increased development activity, which should convert to operating cash flow over time.
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Cash Flows
The following table summarizes the Company’s cash flows:
| Three Months Ended March 31, | ||||||||||||||||||||||||||||||||
| 2026 | 2025 | |||||||||||||||||||||||||||||||
| (In thousands) | ||||||||||||||||||||||||||||||||
| Net cash provided by operating activities | $ | 47,176 | $ | 50,381 | ||||||||||||||||||||||||||||
| Net cash used in investing activities | $ | (28,809) | $ | (25,403) | ||||||||||||||||||||||||||||
| Net cash used in financing activities | $ | (20,447) | $ | (29,245) | ||||||||||||||||||||||||||||
Operating Activities
Net cash provided by operating activities were $47.2 million for the three months ended March 31, 2026, compared to $50.4 million for the three months ended March 31, 2025, and primarily consisted of the following:
| Three Months Ended March 31, | ||||||||||||||
| 2026 | 2025 | |||||||||||||
| (In thousands) | ||||||||||||||
Total revenues, net | $ | 113,881 | $ | 102,457 | ||||||||||
Operating expenses (1) | $ | (41,277) | $ | (32,439) | ||||||||||
Change in accounts receivable | $ | (17,071) | $ | 6,893 | ||||||||||
| Advances from joint interest owners | $ | 12,081 | $ | (5,570) | ||||||||||
| Settlements on derivative contracts | $ | (11,725) | $ | 1,115 | ||||||||||
Interest paid, net of capitalized interest | $ | (5,469) | $ | (5,860) | ||||||||||
Tax liabilities paid | $ | (10,000) | $ | (9,000) | ||||||||||
_____________________
(1)Operating expenses include LOE, production and ad valorem taxes, administrative costs and other minor operating expenses.
The decrease in net cash provided by operating activities was primarily attributable to derivative settlements received in the prior year versus paid in the current year and an increase in accounts receivable, both driven by higher crude oil prices. This was partially offset by an increase in advances from joint interest owners.
Investing Activities
Net cash flows used in investing activities were $28.8 million for the three months ended March 31, 2026, compared to $25.4 million for the three months ended March 31, 2025, and primarily consisted of the following:
| Three Months Ended March 31, | ||||||||||||||
| 2026 | 2025 | |||||||||||||
(In thousands) | ||||||||||||||
| Additions to oil and natural gas properties | $ | (29,570) | $ | (16,150) | ||||||||||
Additions to midstream property and equipment | $ | (1,054) | $ | (2,879) | ||||||||||
| Acquisitions of oil and natural gas properties | $ | (2,175) | $ | — | ||||||||||
Proceeds from divestitures | $ | 7,607 | $ | — | ||||||||||
| Contributions to equity method investment | $ | (4,000) | $ | (6,250) | ||||||||||
Capital expenditures for oil and natural gas properties increased by $13.4 million due to an increase in wells drilled and completed. The Company had proceeds from the sale of non-operated wells in 2026.
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Financing Activities
Net cash flows used in financing activities were $20.4 million for the three months ended March 31, 2026, compared to $29.2 million for the three months ended March 31, 2025, and primarily consisted of the following:
| Three Months Ended March 31, | ||||||||||||||
| 2026 | 2025 | |||||||||||||
(In thousands) | ||||||||||||||
| Repayments under Credit Facility, net | $ | (3,000) | $ | (16,000) | ||||||||||
| Repayments of Senior Notes | $ | (5,000) | $ | (5,000) | ||||||||||
Payment of cash dividends | $ | (8,360) | $ | (8,033) | ||||||||||
Repurchase of common shares | $ | (4,048) | $ | — | ||||||||||
The Company decreased net debt repayments by $13.0 million, partially offset by repurchased common shares of $4.0 million.
Credit Facility and Senior Notes
The borrowing base under the Company's Credit Facility was $400 million with outstanding borrowings of $107 million at March 31, 2026, and $293 million of available borrowing capacity.
The Senior Notes had a principal balance of $140 million as of March 31, 2026.
See further discussion in Note 10 - Long-Term Debt for additional information.
Dividends
For the three months ended March 31, 2026, the Company recognized quarterly dividends totaling approximately $8.6 million, with $8.4 million paid in cash and $0.2 million accrued for the holders of unvested restricted stock awards.
Contractual Obligations
As of March 31, 2026, the Company had a remaining volume commitment of five years with Targa, formerly Stakeholder, in Texas. The Company also had natural gas delivery commitments under the A&R Tolling Agreement and a remaining equity commitment under the Second Amendment to the A&R LLC Agreement to fund our portion of the capital budget for the RPC Power joint venture. The Company also entered into the A&R Gas Purchase Agreement that required an acreage dedication and a minimum volume commitment to Targa for a significant portion of our natural gas production in New Mexico. This agreement is expected to commence before the end of 2026. In addition, the Company entered into the Waterbridge Agreement, which includes minimum produced water volume commitments for a portion of our New Mexico operations and is expected to be in service in September 2026. See Note 15 - Commitments and Contingencies for additional information.
Critical Accounting Estimates
The Company's critical accounting estimates are described in "Critical Accounting Estimates" within "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" in the 2025 Annual Report. The accounting estimates used in preparing our interim condensed consolidated financial statements for the three months ended March 31, 2026, are the same as those described in the 2025 Annual Report.
See Note 3 - Summary of Significant Accounting Policies in the Company's consolidated financial statements in "Item 15. Exhibits and Financial Statement Schedules" in the 2025 Annual Report for a full discussion of our significant accounting policies.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
The primary objective of the following information is to provide both quantitative and qualitative insights into our exposure to market risk. Market risk refers to the potential for financial loss arising from adverse changes in commodity prices and interest rates. These disclosures are not intended to serve as precise forecasts of future losses, but rather to offer a framework for understanding reasonably possible risks. The forward-looking information presented reflects our approach to managing and mitigating market risk exposure within the context of our ongoing operational and financial strategy. All of our market risk sensitive instruments were entered into for purposes other than speculative trading.
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Commodity Price Risk
Our results of operations and cash flows are highly sensitive to fluctuations in the prices of crude oil, natural gas and NGLs. The volatility in these prices is influenced by various factors, including market conditions, geopolitical events, supply-demand imbalances, regulatory changes and other external factors outside of the Company's control. To partially reduce the impact of price volatility on our revenues and cash flows, we utilize commodity-based derivative contracts.
See Note 6 - Derivative Instruments and Note 7 - Fair Value Measurements for a full discussion of our commodity-based derivative contracts and the fair value measurements associated with our derivatives, respectively.
For the three months ended March 31, 2026, oil and natural gas sales, net was $113.9 million, excluding any effect of our derivative contracts. Oil and natural gas sales, net would have increased or decreased by approximately $11.4 million if there was a 10% change in realized pricing. As of March 31, 2026, the fair value of our oil and natural gas derivative contracts was a net liability of $91 million. A 10% change in the forward curves associated with our oil and natural gas derivative contracts would have changed our net position by approximately $61 million.
Interest Rate Risk
Our business is subject to the effects of market interest rates. These interest rates are influenced by macroeconomic factors such as inflation, consumer spending and federal reserve monetary policy. Interest rate risk could increase our cost of capital and potentially slow economic growth, either of which (or the combination thereof) could hurt the financial and operating results of our business. We are also exposed to market risk related to changes in interest rates on our indebtedness under our Credit Facility. To mitigate this risk, the Company utilizes interest rate derivative contracts to partially reduce exposure to interest rate fluctuations.
See Note 10 - Long-Term Debt and Note 6 - Derivative Instruments for a full discussion of our long-term debt and interest rate derivative contracts, respectively.
Item 4. Controls and Procedures
Disclosure Controls and Procedures
Our management establishes and maintains disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) that are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Such information is accumulated and communicated to our management, including our Chief Executive Officer ("CEO") and Chief Financial Officer ("CFO"), as appropriate, to allow timely decisions regarding required disclosure. We evaluated the effectiveness of our disclosure controls and procedures as of March 31, 2026, with the participation of our CEO and CFO, as well as other key members of our management. Based on this evaluation, our CEO and CFO concluded that our disclosure controls and procedures were effective as of March 31, 2026.
Changes in Internal Control Over Financial Reporting
There were no changes in our internal control over financial reporting during the three months ended March 31, 2026, that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
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PART II. OTHER INFORMATION
Item 1. Legal Proceedings
From time to time, we may be involved in various legal proceedings and claims in the ordinary course of business. The ultimate outcome of any such proceedings or claims, and any resulting impact on us, cannot be predicted with certainty. The Company believes that the amount of the liability, if any, ultimately incurred with respect to any such proceedings or claims will not have a material adverse effect on our financial condition, liquidity, capital resources, results of operations or cash flows.
Refer to "Part I, Item 3 - Legal Proceedings" of the 2025 Annual Report, and "Part I, Item 1. Note 15 - Commitments and Contingencies" in the notes to the unaudited condensed consolidated financial statements set forth in this Quarterly Report (which is incorporated by reference herein) for additional information.
Item 1A. Risk Factors
In addition to the information set forth in this Quarterly Report, the risks that are discussed in the Company's Annual Report on Form 10-K for the year ended December 31, 2025, under the headings "Part I, Item 1 and 2. Business and Properties," "Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations" and "Part I, Item 1A. Risk Factors" should be carefully considered, as such risks could materially affect the Company's business, financial condition or future results. Other than those noted below, there have been no material changes in the Company's risk factors from those that were described in the Company's 2025 Annual Report.
Sustained negative or depressed natural gas prices at the Waha Hub, and widening basis differentials between Waha and Henry Hub, have adversely affected, and will continue to adversely affect, our realized natural gas and NGL prices. At times, we may not be able to fully recover our GP&T costs associated with the processing of our natural gas and recovery of our NGLs, resulting in negative natural gas and NGL realized prices, negative revenues and a reduction in our results of operations.
Substantially all of our natural gas production is sold at prices referenced, directly or indirectly, to the Waha Hub in West Texas. The Waha Hub has experienced sustained periods of negative cash pricing driven by Permian Basin natural gas production outpacing available pipeline takeaway capacity to downstream markets along the Texas Gulf Coast, Mexico and the U.S. West Coast. Waha daily cash prices periodically trade in negative territory including a sustained period of consecutive negative days in the first quarter of 2026. This trend has continued into the second quarter of 2026.
At times of negative gas prices, we may have insufficient NGL revenues to fully cover our GP&T costs resulting in negative realized prices for both natural gas and NGLs. Negative or depressed Waha pricing may cause us to curtail, defer, shut in wells or take other actions where the wellhead economics no longer support continued production after deduction of our GP&T costs and related fees. Prolonged negative pricing may also adversely affect the estimated economically producible quantity of our proved reserves and may trigger non-cash impairments to our oil and natural gas reserves.
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Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
Issuer Repurchases of Equity Securities
In December 2025, our Board of Directors approved the Repurchase Program authorizing the repurchase of up to $100 million of our common stock from time to time over a period of 24 months, including through open market purchases, through block trades, in privately negotiated transactions, or by other means, including through the use of trading plans, each in accordance with applicable securities laws and other restrictions. The Repurchase Program does not obligate us to purchase any common stock and may be suspended, modified, extended or discontinued by the Board at any time. During the first quarter of 2026, 152,408 shares were purchased for $4.0 million, or a weighted average price of $26.54 per share, under the Repurchase Program. The remaining repurchase authority under the Repurchase Program at March 31, 2026, was $96 million.
We also receive shares from employees for the payment of personal income tax withholding upon vesting of stock-based compensation transactions. The acquisition of the surrendered shares is not part of our Repurchase Program to repurchase shares of our common stock. Any shares repurchased by the Company for personal tax withholdings are immediately retired upon repurchase.
Our common stock repurchase activity during the first quarter of 2026 was as follows:
| Month Ended | Total Number of Shares Purchased | Average Price Paid per Share | Total Number of Shares Purchased as Part of Publicly Announced Plan or Programs | Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plan or Programs | ||||||||||||||||||||||
| January 31 | 152,744 | $ | 26.54 | 152,408 | $ | 95,954,918 | ||||||||||||||||||||
| February 28 | 151 | $ | 27.50 | — | $ | 95,954,918 | ||||||||||||||||||||
| March 31 | — | $ | — | — | $ | 95,954,918 | ||||||||||||||||||||
Item 5. Other Information
During the quarter ended March 31, 2026, none of our directors or officers (as defined in Rule 16a-1(f) of the Exchange Act) adopted terminated
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Item 6. Exhibits
| Exhibit Number | Description | ||||
2.1 | Securities Purchase Agreement dated May 3, 2025, by and between Silverback Legacy, LLC and Silverback Blocker, LLC, as Seller, and Riley Exploration - Permian, LLC, as Purchaser (incorporated by reference to Exhibit 2.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on May 7, 2025). | ||||
2.2 | Purchase and Sale Agreement dated December 3, 2025, by and between Riley Exploration - Permian, LLC and Targa Northern Delaware LLC (incorporated by reference from Exhibit 2.1 to the Registrant’s Current Report on Form 8-K, as filed with the Securities and Exchange Commission on December 4, 2025). | ||||
3.1 | First Amended and Restated Certificate of Incorporation of Riley Exploration Permian, Inc. (incorporated by reference to Exhibit 4.1 to the Registrant’s Registration Statement on Form S-8 filed with the Securities and Exchange Commission on March 1, 2021, Registration No. 333-253750). | ||||
3.2 | Third Amended and Restated Bylaws of Riley Exploration Permian, Inc. (incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on September 23, 2022). | ||||
4.1 | Description of Registrant's Securities (incorporated by reference to Exhibit 4.1 to the Registrant’s Annual Report on Form 10-K, as filed with the Securities and Exchange Commission on March 6, 2024). | ||||
4.2 | Note Purchase Agreement, dated as of April 3, 2023, among Riley Exploration - Permian, LLC, as Issuer, Riley Exploration Permian, Inc., as Parent, each of the subsidiaries of the Issuer party thereto as guarantors, each of the holders from time to time party thereto, and U.S. Bank Trust Company, National Association, as agent for the holders (incorporated by reference to Exhibit 4.1 to the Registrant's Current Report on Form 8-K filed with the Securities and Exchange Commission on April 4, 2023). | ||||
4.3 | First Amendment to Note Purchase Agreement dated as of December 13, 2024 by and among Riley Exploration - Permian, LLC, as Issuer, Riley Exploration Permian, Inc., as Parent, each of the subsidiaries of the Issuer party thereto as guarantors, each of the holders from time to time party thereto, and U.S. Bank Trust Company, National Association, as agent for the holders (incorporated by reference from Exhibit 10.2 to the Registrant’s Current Report on Form 8-K, as filed with the Securities and Exchange Commission on December 18, 2024). | ||||
10.1† | Amendment No. 1 to Amended and Restated Employment Agreement dated March 26, 2025 with an effective date of March 3, 2026 by and between Riley Exploration Permian, Inc. and Bobby D. Riley (incorporated by reference to Exhibit 10.35 to the Registrant’s Annual Report on Form 10-K, as filed with the Securities and Exchange Commission on March 4, 2026). | ||||
10.2* | Eighteenth Amendment to the Credit Agreement dated as of April 30, 2026, by and among Riley Exploration Permian, Inc., Riley Exploration - Permian, LLC, as borrower, Truist Bank, as administrative agent, and the lenders party thereto. | ||||
31.1* | Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | ||||
31.2* | Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | ||||
32.1* | Certification of Chief Executive Officer pursuant to 18 U.S.C., Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | ||||
32.2* | Certification of Chief Financial Officer pursuant to 18 U.S.C., Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | ||||
| 101.INS* | XBRL Instance Document | ||||
| 101.SCH* | XBRL Taxonomy Extension Schema Document | ||||
| 101.CAL* | XBRL Taxonomy Calculation Linkbase Document | ||||
| 101.DEF* | XBRL Taxonomy Definition Linkbase Document | ||||
| 101.LAB* | XBRL Taxonomy Label Linkbase Document | ||||
| 101.PRE* | XBRL Taxonomy Presentation Linkbase Document | ||||
* Filed herewith.
† Compensatory plan or arrangement.
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SIGNATURES
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.
| RILEY EXPLORATION PERMIAN, INC. | ||||||||
Date: May 6, 2026 | By: | /s/ Bobby Riley | ||||||
Bobby Riley | ||||||||
| Chairman of the Board and Chief Executive Officer | ||||||||
| By: | /s/ Philip Riley | |||||||
| Philip Riley | ||||||||
| Chief Financial Officer and Executive Vice President of Strategy | ||||||||
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FAQ
How did Riley Exploration Permian (REPX) perform financially in Q1 2026?
Riley Permian posted a Q1 2026 net loss of $70.4M, compared with net income of $28.6M a year earlier. The company generated $113.9M in oil and gas sales, net, and $47.2M of operating cash flow, while absorbing a large derivative loss.
What drove the Q1 2026 net loss for Riley Exploration Permian (REPX)?
The net loss was driven primarily by a $126.97M loss on derivatives, mostly from changes in fair value of commodity hedges. Core operations produced income from operations of $43.7M, but the hedge-related loss and other expenses turned results negative overall.
How did production and realized prices change for Riley Permian (REPX) in Q1 2026?
Total production rose to 35,600 Boe/d, up from 24,433 Boe/d, with oil volumes increasing to 20,156 Bbls/d. Realized oil prices slipped slightly to $68.89 per Bbl, while natural gas and NGL prices were negative after GP&T costs due to weak regional pricing.
What is Riley Exploration Permian’s (REPX) debt and liquidity position?
At March 31, 2026, total debt was $240.7M, including $107M on the Credit Facility and $133.7M of Senior Notes (net of discounts). With a $400M borrowing base, the company had $293M of available capacity, supporting ongoing development and commitments.
How much cash flow and capital spending did Riley Permian (REPX) report for Q1 2026?
Net cash provided by operating activities was $47.2M in Q1 2026. Accrual capital expenditures before acquisitions were $47.1M, largely directed to oil and natural gas properties. This left cash roughly stable while funding growth-oriented drilling and infrastructure investments.
What shareholder returns did Riley Exploration Permian (REPX) provide around Q1 2026?
The company declared Q1 2026 common dividends totaling about $8.6M and later approved a $0.40 per share dividend payable in May 2026. It also repurchased and retired 152,408 shares under a $100M buyback program, leaving $96M of remaining authorization.
How is the Silverback acquisition affecting Riley Permian’s (REPX) results?
The July 2025 Silverback acquisition contributed $14.2M of Q1 2026 revenues and $8.4M of earnings before production taxes and LOE. It increased depletion expense and added a contingent earnout liability, which rose to $7.2M as WTI strip prices moved higher.