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"Our 2024 performance demonstrates the capital efficiency of our asset base. Moving to 2025, we will invest strategically across our business with a focus on securing our future long-term growth. We continue to experience efficiency improvements in our upstream business, and this year we plan to shift increased development activity to New Mexico. We are excited to advance our New Mexico gas midstream project, which we believe will afford us increased operational control of our gas gathering and regional transportation and provide greater flow assurance for long-term growth from our New Mexico assets. Finally, we're progressing with our power projects within our joint venture and continue to see attractive market fundamentals in ERCOT."

OPERATIONS AND DEVELOPMENT ACTIVITY UPDATE

The tables below provide a summary of our operated well activity and acreage statistics:

Net Acreage by State

FOURTH QUARTER 2024 FINANCIAL RESULTS

Revenues totaled $103 million, net cash provided by operating activities was $66 million and net income was $11 million, or $0.52 per diluted share.

On a non-GAAP basis, Adjusted EBITDAX⁽¹⁾ was $69 million, cash flow from operations before changes in working capital⁽¹⁾ was $51 million, Total Free Cash Flow⁽¹⁾ was $18 million and Adjusted Net Income⁽¹⁾ was $20 million, or $0.96 per diluted share.

Average realized prices, before derivative settlements, were $68.50 per barrel of oil, $0.02 per Mcf of natural gas and $5.18 per barrel of natural gas liquids. The Company reported a $8 million loss on derivatives, which included a $3 million realized gain on settlements and a $11 million non-cash loss due to changes in the fair value of derivatives.

Operating expenses included lease operating expense ("LOE") of $20 million, or $8.54 per Boe, cash G&A expense⁽¹⁾ of $9 million, or $3.77 per Boe, inclusive of severance and other non-recurring charges, and production and ad valorem taxes of $8 million or $3.48 per Boe.

The Company incurred $31 million in total accrued capital expenditures ($20 million for upstream). On a cash basis, the Company had total capital expenditures of $33 million ($22 million for upstream).

The Company reduced total debt by $20 million, including a principal reduction of $15 million on the Credit Facility and $5 million on the Senior Notes. Interest expense, net was $8 million.

The Company paid a cash dividend of $0.38 per share, for a total of $8 million.

YEAR ENDED 2024 FINANCIAL RESULTS

Revenues totaled $410 million, net cash provided by operating activities was $246 million and net income was $89 million, or $4.26 per diluted share.

On a non-GAAP basis, Adjusted EBITDAX⁽¹⁾ was $284 million, cash flow from operations before changes in working capital⁽¹⁾ was $227 million, Total Free Cash Flow⁽¹⁾ was $117 million and Adjusted Net Income⁽¹⁾ was $117 million or $5.59 per diluted share.

The Company reported a $2 million loss on derivatives, which included a $2 million realized gain on settlements and a $4 million non-cash loss due to changes in the fair value of derivatives.

Operating expenses included LOE of $71 million, or $8.66 per Boe, cash G&A expense⁽¹⁾ of $27 million, or $3.22 per Boe, inclusive of severance and other non-recurring charges, and production and ad valorem taxes of $29 million or $3.57 per Boe.

The Company incurred $108 million in total accrued capital expenditures ($97 million for upstream). On a cash basis, the Company had total capital expenditures of $110 million ($99 million for upstream).

The Company reduced total debt by $90 million, net of proceeds, including a principal reduction of $70 million on the Credit Facility and $20 million on the Senior Notes. Interest expense, net was $34 million.

The Company had $269 million of total debt as of December 31, 2024, including $115 million drawn on our Credit Facility (with approximately $285 million available for future borrowing) and $154 million of Senior Notes. On a principal basis, the Company had $280 million of total debt, including $165 million principal value of Senior Notes.

The Company paid dividends of $1.46 per share for a total of $31 million.

Shareholder's equity was $511 million as of December 31, 2024, an increase of 21% year-over-year and the number of common shares outstanding was 21.5 million, an increase of 5% year-over-year.

RESERVES

Estimates of Riley Permian's proved reserves as of December 31, 2024, were prepared by Ryder Scott Company, L.P., the Company's third-party reservoir engineer, using the SEC pricing methodology. Proved reserves at year-end 2024 of 124 MMBoe increased by 16 MMBoe or 15% over year-end 2023 reserves. Oil represented 54% of total proved reserves. Proved developed producing reserves ("PDP") increased by 27% to 77 MMBoe, which represented 62% of total proved reserves. Proved undeveloped reserves ("PUD") decreased slightly to 47 MMBoe, when compared to year-end 2023. At December 31, 2024, the standardized measure of discounted cash flows and PV-10⁽¹⁾ were $1,242 million and $1,543 million, respectively.

The net proved reserve additions resulted in a reserve replacement ratio (defined as the sum of extensions and discoveries, revisions, acquisitions and divestitures, divided by annual production) of 293% for the year ended December 31, 2024. The organic reserve replacement ratio (defined as the sum of extensions and discoveries and revisions, divided by annual production) was 241%.

Extensions and discoveries were the primary contributor to the increase in reserves of 16 MMBoe, which consisted of 8 MMBoe added to PDP as a result of drilling successful wells that were previously classified as unproved locations, and 8 MMBoe added to PUDs as a result of drilling activity during the year, which allowed for the booking of adjacent PUDs for locations that were previously booked as unproved reserves or not at all. The Company also acquired 4 MMBoe in reserves. The Company had production of 8 MMBoe and positive revisions of previous estimates of 4 MMBoe.

NEW MEXICO GAS MIDSTREAM PROJECT

We believe the successful execution of the Company's New Mexico development plan is dependent upon maintaining operational control and securing reliable processing and downstream markets for our natural gas. As part of this plan, and as previously disclosed, the Company signed a long-term gas purchase agreement with a leading third-party midstream service provider ("Midstream Counterparty"). Under this gas purchase agreement, the Midstream Counterparty is obligated to process, treat and purchase from Riley Permian, and Riley Permian is obligated to sell to the Midstream Counterparty, all of the committed gas and natural gas liquids from dedicated acreage.

Additionally, Riley Permian intends to construct, own and operate low and high-pressure gathering lines and compression facilities that will connect to our new high-capacity 20-inch natural gas pipeline designed to handle gas volumes of up to 150MMcf per day. We anticipate the first compressor station will be in-service during March 2025, which will initially connect to our existing processing and treating counterparty. Subsequently, we plan to begin the construction of additional gathering systems and the pipeline, with an estimated completion before the end of 2026, at which point all newly-built gathering, compression stations and the pipeline will connect to the new Midstream Counterparty's network.

The Board of Directors approved an aggregate of approximately $130 million in capital expenditures to complete these initial projects of our midstream buildout plan. An estimated range of 2025 capital expenditures for this project has been provided in this release, which could vary materially given timing changes from our base plan. The Company currently intends to fund these capital expenditures using a combination of operating cash flow, cash on hand and from borrowings on its credit facility, as needed.

 

2025 GUIDANCE

Riley Permian is providing first quarter detailed guidance and select full-year 2025 activity 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. Total equivalent production estimates, inclusive of production from natural gas and NGLs, may be subject to variability based on midstream conditions. In the event our midstream project is delayed, it may have corresponding impacts on net production volumes and investing expenditures.

CONFERENCE CALL
In connection with the earnings release, Riley Permian management will host a conference call for investors and analysts on March 6, 2025 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 (888) 596-4144

• Toll Dial-in, +1 (646) 968-2525

• Conference ID number 1303008

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). In addition to a webcast of the call available on the Company's website, a replay of the call will be available until March 20, 2025 by calling:

• Toll Free Dial-In, +1 (800) 770-2030

• Toll Dial-in, +1 (609) 800-9909

• Conference ID number 1303008

About Riley Exploration Permian, Inc.
Riley Permian is a growth-oriented, independent oil and natural gas company focused on the acquisition, exploration, development and production of oil, natural gas and natural gas liquids. For more information, please visit www.rileypermian.com.

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

Cautionary Statement Regarding Forward Looking Information

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; 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 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 its 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 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 for development and exploration and midstream operations 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 Railroad Commission of Texas 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 the military conflict between Russia and Ukraine, conflicts in the Middle East, and the global response to such conflicts; risks related to litigation; and cybersecurity threats, technology system failures and data security issues. Additional factors that could cause results to differ materially from those described above can be found in Riley Permian's Annual Report on Form 10-K for the year ended December 31, 2024 filed with the SEC and available from the Company's website at www.rileypermian.com under the "Investor" tab, and in other documents the Company files with the SEC.

The forward-looking statements in this press release are made as of the date hereof and are based on information available at that time. The Company does not undertake, and expressly disclaims, any duty to update or revise our forward-looking statements based on new information, future events or otherwise.

Cautionary Statement Regarding Guidance

The estimates and guidance presented in this release are based on assumptions of current and future capital expenditure levels, prices for oil, natural gas and NGLs, available liquidity, indications of supply and demand for oil, well results, and operating costs. The guidance provided in this release does not constitute any form of guarantee or assurance that the matters indicated will be achieved. While we believe these estimates and the assumptions on which they are based are reasonable as of the date on which they are made, they are inherently uncertain and are subject to, among other things, significant business, economic, operational, and regulatory risks, and uncertainties, some of which are not known as of the date of the statement. Guidance and estimates, and the assumptions on which they are based, are subject to material revision. Actual results may differ materially from estimates and guidance. Please read the "Cautionary Statement Regarding Forward Looking Information" section above, as well as "Risk Factors" in our annual report on Form 10-K and our quarterly reports on Form 10-Q, which are incorporated herein.

 

 

OIL, NATURAL GAS AND NGL RESERVES

Estimates of Riley Permian's proved reserves as of December 31, 2024, were prepared by Ryder Scott Company, L.P. ("Ryder Scott"), the Company's third-party reservoir engineer. Estimates of proved reserves were prepared in accordance with the rules and regulations of the SEC using an average price equal to the unweighted arithmetic average of the first day of each month within the 12-month period ended December 31, 2024, of $76.32 per Bbl for oil and $2.13 per Mcf for gas. Additionally, the Company prepared estimates of proved reserves as of December 31, 2024, using NYMEX pricing, which were not reviewed by Ryder Scott. The table below presents a summary of our proved reserves as of December 31, 2024.

 

Reserve estimates above do not include any value for probable or possible reserves that may exist, nor do they include any value for undeveloped acreage. The reserve estimates represent our net revenue interest in our properties, all of which are located within the continental United States. NYMEX pricing does not comport with the reporting requirements of the SEC and should not be used as a substitute for or compared with estimates of proved reserves using SEC pricing.

OIL, NATURAL GAS AND NGL RESERVES, Continued

Ryder Scott prepared the estimates of the Company's proved reserves as of December 31, 2023, in accordance with the rules and regulations of the SEC using an average price equal to the unweighted arithmetic average of the first day of each month within the 12-month period ended December 31, 2023, of $78.22 per Bbl for oil and $2.64 per Mcf for natural gas. The Company prepared estimates of proved reserves as of December 31, 2023, using NYMEX pricing, which were not reviewed by Ryder Scott. The table below presents a summary of our proved reserves as of December 31, 2023.

 

Reserve estimates above do not include any value for probable or possible reserves that may exist, nor do they include any value for undeveloped acreage. The reserve estimates represent our net revenue interest in our properties, all of which are located within the continental United States. NYMEX pricing does not comport with the reporting requirements of the SEC and should not be used as a substitute for or compared with estimates of proved reserves using SEC pricing.

DERIVATIVE CONTRACTS

The Company's oil and natural gas derivative instruments consisted of fixed price swaps and costless collars. The following table summarizes the open financial derivatives as of February 28, 2025, related to oil and natural gas production:

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 CME Term Secured Overnight Financing Rate and will pay a fixed interest rate, to manage future interest rate exposure related to the Company's Credit Facility. In March 2024, the Company entered into a fixed-to-floating interest rate swap for the period May 2024 to December 2024, to reduce our interest rate exposure, which resulted in a gain of approximately $1 million for the year ended December 31, 2024, on a notional amount of $80 million, and is included in our consolidated statements of operations.

The following table summarizes the open interest rate derivative positions as of December 31, 2024:

 

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SOURCE Riley Exploration Permian, Inc.