Riley Exploration Permian, Inc. press release

Riley Permian Reports Third Quarter 2026 Results

2026-11-04

NYSE - New York Stock Exchange · Oil · Natural Gas · Natural Gas Liquids · United States · Corporate Finance

PR Newswire

OKLAHOMA CITY, Nov. 4, 2026/PRNewswire/ -- Riley Exploration Permian, Inc. (NYSE American: REPX) ("Riley Permian" or the "Company"), today reported financial and operating results for the third quarter ended September 30, 2026.

THIRD QUARTER 2026 HIGHLIGHTS

Increased oil production by 20% quarter-over-quarter (+38% year-over-year) to 25.4 MBbls/d, with total equivalent production of 42.0 MBoe/d Grew operating cash flow 75% quarter-over-quarter (+75% year-over-year) to $111 million and $42 million of Total Free Cash Flow(1) Incurred total accrual capital expenditures before acquisitions of $53 million and cash capital expenditures before acquisitions of $66 million Reduced debt by 10% quarter-over-quarter (-35% year-over-year) to $245 million

ADDITIONAL UPDATES

Commenced operations over the past seven weeks on new third-party water and gas infrastructure in New Mexico, including natural gas gathering and high pressure trunkline system developed over the past year Progressed organic resource expansion initiatives across the Red Lake asset, including evaluation of the San Andres formation with planned development activity beginning in the second quarter of 2027 Retired 10.5% unsecured senior notes ("Senior Notes") in October 2026 Increased quarterly dividend by 5% to $0.42 per share in October 2026

MANAGEMENT COMMENTARY

The Company reported strong results across operating and financial metrics. Production growth was driven by new development well volumes from capital invested in prior quarters, as well as the return to production of select New Mexico wells following disruptions during the second quarter. Stronger natural gas and NGL realizations resulted in a $22 million positive swing in revenue compared to the second quarter, when we experienced negative revenue on those products. Core operating costs also improved on a per unit basis, contributing to stronger margins.

Bobby Riley, CEO and Chairman of the Board, stated, "Going forward, and based on current market conditions, we plan to continue investing significantly in the development of our assets, supported by our large and growing base of undeveloped inventory, improving third-party infrastructure conditions, and the currently supportive commodity price environment."

| | | | (1) | A non-GAAP financial measure as defined and reconciled in the supplemental financial tables available on the Company's website at www.rileypermian.com. |

THIRD QUARTER 2026 OPERATIONS AND DEVELOPMENT ACTIVITY RESULTS

Average Daily Production by State

| | | Three Months Ended September 30, | | Nine Months Ended September 30, | | | | | | | | 2026 | | 2025 | | 2026 | | 2025 | | Total Equivalent Production (MBoe/d) | | | | | | | | | | Texas | | 27.7 | | 17.2 | | 24.1 | | 17.0 | | New Mexico | | 14.3 | | 15.1 | | 13.2 | | 10.1 | | Total | | 42.0 | | 32.3 | | 37.3 | | 27.1 | | | | | | | | | | | | Oil Production (MBbls/d) | | | | | | | | | | Texas | | 18.5 | | 10.5 | | 15.7 | | 11.2 | | New Mexico | | 6.9 | | 7.9 | | 6.6 | | 5.2 | | Total | | 25.4 | | 18.4 | | 22.3 | | 16.4 |

Development Activity by State

| | | Three Months Ended September 30, 2026 | | Nine Months Ended September 30, 2026 | | | | | | | | Gross(1) | | Net(2) | | Gross(1) | | Net(2) | | Wells Drilled | | | | | | | | | | Texas | | 5 | | 4.1 | | 30 | | 28.5 | | New Mexico | | 8 | | 4.5 | | 24 | | 15.6 | | Total | | 13 | | 8.6 | | 54 | | 44.1 | | | | | | | | | | | | Wells Completed | | | | | | | | | | Texas | | 7 | | 6.5 | | 38 | | 36.6 | | New Mexico | | 2 | | 1.4 | | 2 | | 1.4 | | Total | | 9 | | 7.9 | | 40 | | 38.0 | | | | | | | | | | | | Wells Turned to Sales | | | | | | | | | | Texas | | 12 | | 11.9 | | 35 | | 33.8 | | New Mexico | | — | | — | | — | | — | | Total | | 12 | | 11.9 | | 35 | | 33.8 |

| | | | (1) | Gross wells are the total number of operated wells in which the Company has an interest | | (2) | Net wells are gross wells multiplied by our fractional working interest |

Production increased in Texas for both the three months and nine months periods ending September 30, 2026, primarily from the contribution of new wells turned to sales. Year-to-date, all of the Company's new wells turned to sales have been in Texas.

Production increased in New Mexico quarter-over-quarter primarily from the return to normal operations in most areas following shut-ins from third-party midstream constraints experienced in the second quarter. Production decreased in New Mexico year-over-year for the three months ended September 30, 2026, due to natural decline, as zero new wells were turned to sales since July 2025, while production increased year-over-year for the nine months ended September 30, 2026 as a result of workover activity and the acquisition of Silverback Exploration II, LLC and its subsidiaries on July 1, 2025.

Year-to-date, the Company drilled 44.1 net wells, completed 38.0 net wells and turned to sales 33.8 net wells. The Company exited the third quarter with 17.3 net drilled-but-uncompleted wells, including 2.6 net wells in Texas and 14.7 net wells in New Mexico, with an additional 5.9 net completed wells not yet turned to sales. Wells are scheduled to turn to sales in the coming quarters across both regions.

THIRDQUARTER2026FINANCIAL RESULTS

Revenues totaled $201 million, operating income was $107 million, operating cash flow was $111 million and net loss was $2 million, or $(0.11) per diluted share.

On a non-GAAP basis, Adjusted EBITDAX(1)was $117 million, cash flow from operations before changes in working capital(1)was $108 million, Total Free Cash Flow(1) was $42 million and Adjusted Net Income(1)was $56 million, or $2.66 per diluted share.

Average realized prices, before derivative settlements, were $83.63 per barrel of oil, $0.27 per Mcf of natural gas and $5.08 per barrel of natural gas liquids ("NGL"). Total revenues increased $35 million or 21% quarter-over-quarter, as higher volumes and positive natural gas and NGL revenue more than offset a $10.65/Bbl decline in realized oil price before derivative settlements.

The Company reported a $28 million realized loss on derivative settlements, reflecting cash settlements on financial contracts linked to crude oil prices, and a $72 million non-cash loss due to the changes in the fair value of derivatives that will settle in future periods for a combined $100 million net loss on derivatives. Unrealized derivatives reflect the accounting remeasurement of the Company's derivative portfolio based on changes in the market value of contracts that remain open and do not represent current-period cash inflows or outflows.

Revenue net of derivative settlements increased $43 million or 33% quarter-over-quarter to $173 million, with oil accounting for 31% of the positive variance, natural gas and NGL accounting for 51% of the variance, and derivative settlements accounting for 18%.

Operating expenses included lease operating expense of $34 million, or $8.84 per Boe, which included $11 million in workover expense. Administrative costs were $9 million, or $2.27 per Boe and production and ad valorem taxes were $13 million or $3.30 per Boe.

The Company incurred $53 million in total accrued capital expenditures. On a cash basis, the Company had total capital expenditures of $66 million. The Company invested $2 million in its power-focused joint venture, RPC Power.

The Company reduced total debt by $28 million, including a $23 million decrease on the Credit Facility and $5 million reduction on the Senior Notes. As of September 30, 2026, the Company had $115 million of borrowings outstanding on its Credit Facility and $130 million principal value of its Senior Notes, for a combined principal value of debt of $245 million. Interest expense, net was $7 million.

The Company paid a cash dividend of $0.40 per share, for a total of $8 million. Subsequent to quarter-end, the Company declared a cash dividend of $0.42 per share, a 5% increase from the prior quarter. The Company completed zero buybacks during the quarter. As of September 30, 2026, there were 22.15 million shares outstanding, including unvested shares, a year-over-year increase of 0.7%.

| | | | (1) | A non-GAAP financial measure as defined and reconciled in the supplemental financial tables available on the Company's website atwww.rileypermian.com. |

INFRASTRUCTURE UPDATES

In December of 2025, we contracted with Targa Northern Delaware LLC ("Targa") to construct new gathering and high-pressure trunkline infrastructure in Eddy County, New Mexico pursuant to the A&R Gas Purchase Agreement, to mitigate processing and takeaway constraints. On October 1, 2026, the new Targa pipeline system was placed in service.

In January of 2026, the Company entered into a 15-year water management services agreement with Waterbridge Stateline LLC to deliver a portion of its New Mexico produced water for disposal purposes within a specified dedicated area. The in-service date occurred on September 15, 2026.

The additional natural gas infrastructure and water management services agreement are expected to improve natural gas flow assurance and expand water handling capacity to support increased development of the Company's New Mexico acreage position.

DEBT FINANCING UPDATES

On October 5, 2026, the Company voluntarily prepaid in full all of its outstanding Senior Notes, which was $130 million plus $0.2 million of accrued interest through the prepayment date. The Company funded the prepayment with borrowings under its existing revolving credit facility ("Credit Facility").

On October 29, 2026, the Company entered into an amended and restated credit agreement to the Credit Facility, which among other things, increased the Company's borrowing base from $425 million to $450 million and increased the elected commitments from $400 million to $450 million. The maturity date was extended to October 2030, and the minimum hedging requirement was reduced to a rolling 18-month basis, down from 24 months.

POTENTIAL RESOURCE EXPANSION

The Company continues to advance geological and reservoir evaluation of the San Andres formation across its Red Lake asset, a productive interval located above the Blinebry and Paddock formations, where modern horizontal development has historically been concentrated. The Company's evaluation incorporates well logs, seismic and other subsurface data, reservoir performance and depletion analysis, as well as recent results from industry development activity in the San Andres. Based on this work, the Company plans to allocate capital to initial development of the San Andres during the second quarter of 2027.

| Selected Operating and Financial Data | | | | | | | | | | | | (Unaudited) | | | | | | | | | | | | | | Three Months Ended | | Nine Months Ended | | | | | | | | | | September 30, 2026 | | June 30, 2026 | | September 30, 2025 | | September 30, 2026 | | September 30, 2025 | | Selected Financial Data (in thousands): | | | | | | | | | | | | Oil and natural gas sales, net | | $ 201,203 | | $ 165,850 | | $ 106,852 | | $ 480,934 | | $ 294,703 | | Income from operations | | $ 106,725 | | $ 87,232 | | $ 28,862 | | $ 237,627 | | $ 107,118 | | Net income (loss) | | $ (2,400) | | $ 87,370 | | $ 16,340 | | $ 14,536 | | $ 75,443 | | Adjusted EBITDAX(1) | | $ 117,287 | | $ 80,107 | | $ 64,041 | | $ 258,327 | | $ 194,514 | | Cash flow from operations | | $ 111,303 | | $ 63,500 | | $ 63,650 | | $ 221,979 | | $ 147,671 | | | | | | | | | | | | | | Upstream accrual capital expenditures | | $ 53,114 | | $ 86,599 | | $ 13,129 | | $ 186,800 | | $ 54,581 | | Upstream cash capital expenditures | | $ 65,446 | | $ 67,931 | | $ 14,893 | | $ 163,507 | | $ 56,467 | | Total accrual capital expenditures | | $ 53,114 | | $ 86,599 | | $ 18,019 | | $ 186,800 | | $ 69,805 | | Total cash capital expenditures | | $ 65,581 | | $ 68,287 | | $ 29,027 | | $ 165,052 | | $ 76,895 | | | | | | | | | | | | | | Upstream Free Cash Flow(1) | | $ 42,486 | | $ 6,613 | | $ 39,441 | | $ 73,653 | | $ 99,998 | | Total Free Cash Flow(1) | | $ 42,351 | | $ 6,257 | | $ 25,307 | | $ 72,108 | | $ 79,570 | | | | | | | | | | | | | | Production Data, net: | | | | | | | | | | | | Oil (MBbls) | | 2,340 | | 1,933 | | 1,690 | | 6,087 | | 4,478 | | Natural gas (MMcf) | | 3,898 | | 3,241 | | 3,380 | | 10,920 | | 7,821 | | NGLs (MBbls) | | 876 | | 645 | | 722 | | 2,281 | | 1,609 | | Total equivalent (MBoe) | | 3,866 | | 3,118 | | 2,975 | | 10,188 | | 7,391 | | | | | | | | | | | | | | Daily equivalent production (Boe/d) | | 42,022 | | 34,264 | | 32,337 | | 37,319 | | 27,073 | | Daily oil production (Bbls/d) | | 25,435 | | 21,242 | | 18,370 | | 22,297 | | 16,403 | | | | | | | | | | | | | | Average Realized Prices:(2) | | | | | | | | | | | | Oil ($ per Bbl) | | $ 83.63 | | $ 94.28 | | $ 63.94 | | $ 82.62 | | $ 65.33 | | Natural gas ($ per Mcf) | | $ 0.27 | | $ (4.12) | | $ (0.21) | | $ (1.71) | | $ 0.00 | | NGLs ($ per Bbl) | | $ 5.08 | | $ (4.71) | | $ (0.66) | | $ (1.46) | | $ 1.34 | | | | | | | | | | | | | | Average Realized Prices, including the effects of derivative settlements:(2)(3) | | | | | | | | | | | | Oil ($ per Bbl) | | $ 71.61 | | $ 74.25 | | $ 65.17 | | $ 69.70 | | $ 67.28 | | Natural gas ($ per Mcf) | | $ 0.26 | | $ (3.33) | | $ (0.16) | | $ (1.48) | | $ (0.02) | | NGLs ($ per Bbl) | | $ 5.08 | | $ (4.71) | | $ (0.66) | | $ (1.46) | | $ 1.34 | | | | | | | | | | | | | | Basic weighted average common shares outstanding (in thousands)(4) | | 20,945 | | 20,937 | | 21,164 | | 20,918 | | 21,139 | | Diluted weighted average common shares outstanding (in thousands)(5) | | 20,945 | | 21,255 | | 21,263 | | 21,221 | | 21,178 |

| | | | (1) | A non-GAAP financial measure as defined and reconciled in the supplemental financial tables available on the Company's website at www.rileypermian.com. | | (2) | The Company's oil, natural gas and NGL sales are presented net of gathering, processing and transportation costs. These costs, related to natural gas and NGLs, at times exceeded the price received and resulted in negative average realized prices. | | (3) | 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 income (expense) on the Company's condensed consolidated statements of operations. | | (4) | Excludes all unvested shares. | | (5) | Excludes potentially dilutive shares that would have been anti-dilutive. Performance shares are included based on performance achieved through September 30, 2026. For periods with a net loss, all potentially dilutive securities are excluded, as their effect would be anti-dilutive. |

2026 GUIDANCE

Riley Permian is providing fourth quarter detailed guidance based on currently scheduled development activity and current market conditions. The average working interest on gross operated wells drilled is subject to change and may have corresponding impacts on net production volumes and investing expenditures.

| Activity and Production | | Q4 2026 | | Net Operated Well Activity | | | | Drilled (#) | | 13 - 17 | | Completed (#) | | 13 - 17 | | Turned to Sales (#) | | 14 - 18 | | | | | | Non-Operated, Net (#) | | 0 - 1 | | | | | | Net Production | | | | Oil (MBbls/d) | | 25.5 - 26.5 | | Total Equivalent (MBoe/d) | | 42.5 - 43.5 | | | | | | Capital Expenditures and Investments (in millions)(1) | | | | Upstream | | $60 - $70 | | Infrastructure and Other | | $14 - $16 | | Total Capital Expenditures | | $74 - $86 | | | | | | Power JV Investment | | $2 | | Total Investments | | $76 - $88 |

| Operating and Corporate Costs | | Q4 2026 | | Lease Operating Expenses ($ per Boe) | | $8.75 - $9.75 | | Production and Ad Valorem Taxes (% of Revenue) | | 7.5% - 8.5% | | Administrative Costs ($ per Boe) | | $2.00 - $2.50 |

| | | | (1) | Accrual (activity-based) investing expenditures before acquisitions |

CONFERENCE CALL In connection with the earnings release, Riley Permian management will host a conference call for investors and analysts on November 5, 2026 at 9:00 a.m. CT to discuss the Company's results and to host a Q&A session. Interested parties are invited to participate by calling:

Toll Free Dial-In, +1 (833) 461-5787 Toll Dial-in, +1 (585) 542-9983 Meeting ID number 124 912 180

An updated company presentation, which will include certain items to be discussed on the call, will be posted prior to the call on the Company's website (www.rileypermian.com).

A replay of the call will be available until November 19, 2026 by calling:

Toll Free Dial-In, +1 (833) 309-1852 Meeting ID number 124 912 180

AboutRiley Exploration Permian, Inc. Riley Permian is a growth-oriented upstream oil and gas company operating in Texas and New Mexico with infrastructure projects that complement our operations. For more information, please visit www.rileypermian.com.

Investor Contact: Ben McQueen 405-438-0126 IR@rileypermian.com

Cautionary Statement Regarding Forward Looking Information and Guidance This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements contained in this release that are not historical facts are forward-looking statements that represent management's beliefs and assumptions based on currently available information. Forward-looking statements include information concerning our possible or assumed future results of operations, business strategies, need for financing, competitive position and potential growth opportunities. Our forward-looking statements 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," "forecasts" or comparable terminology or by discussions of strategy or trends. You should not place undue reliance on these forward-looking statements. These forward-looking statements are subject to a number of risks, uncertainties and assumptions. Moreover, we operate in a very competitive and rapidly changing environment. New risks emerge from time to time. It is not possible for our management to predict all risks, nor can we assess the impact of all factors on our business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements we may make. Although we believe that our plans, intentions and expectations reflected in or suggested by the forward-looking statements we make in this release are reasonable, we can give no assurance that these plans, intentions or expectations will be achieved or occur, and actual results could differ materially and adversely from those anticipated or implied by the forward-looking statements.

Among the factors that could cause actual future results to differ materially are the risks and uncertainties the Company is exposed to. While it is not possible to identify all factors, 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, including uncertainties in San Andres development, well spacing and the applicability of offset-well results to our acreage; 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 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 any potential moratorium on new produced water well permits recently imposed by the Railroad Commission of Texas or New Mexico Oil Conservation Division in an effort to control induced seismicity in the Permian Basin; 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 crisis, 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.