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RILEY PERMIAN Q2'26 Investor Presentation August 2026
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2 Forward-Looking Statements This presentation contains projections and other forward-looking statements within the meaning of federal securities laws. These projections and statements reflect Riley Exploration Permian, Inc.’s (“Riley Permian”) current views with respect to future events and financial performance. No assurances can be given, however, that these events will occur or that these projections will be achieved, and actual results could differ materially from those projected as a result of certain factors. A discussion of these factors is included in Riley Permian’s periodic reports filed with the U.S. Securities and Exchange Commission (“SEC”). All statements, other than historical facts, that address activities that Riley Permian assumes, plans, expects, believes, intends or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward-looking statements are based on management’s current beliefs, based on currently available information, as to the outcome and timing of future events, including 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 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 and 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 revolving 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 rate 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 and midstream project 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 RRC or NMOCD 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. These forward-looking statements involve certain risks and uncertainties that could cause the results to differ materially from those expected by the management of Riley Permian. These forward-looking statements involve a number of risks and uncertainties that could cause actual results to differ materially from those suggested by the forward-looking statements. Riley Permian encourages readers to consider the risks and uncertainties associated with projections and other forward-looking statements. In addition, Riley Permian assumes no obligation to publicly revise or update any forward-looking statements based on future events or circumstances. For additional discussion of the factors that may cause us not to achieve our financial projections and/or production estimates, see Riley Permian’s filings with the SEC, including its forms 10-K, 10-Q and 8-K and any amendments thereto. We do not undertake any obligation to release publicly the results of any future revisions we may make to this prospective data or to update this prospective data to reflect events or circumstances after the date of this presentation. Therefore, you are cautioned not to place undue reliance on this information. None of the information contained in this presentation has been audited by any independent auditor. This presentation is prepared as a convenience for securities analysts and investors and may be useful as a reference tool. Riley Permian may elect to modify the format or discontinue publication at any time, without notice to securities analysts or investors. Use of non-GAAP Financial Information This presentation includes certain financial measures that are not calculated in accordance with U.S. generally accepted accounting principles (“GAAP”). These measures include (i) Adjusted Net Income, (ii) Adjusted EBITDAX, and (iii) Free Cash Flow (including Upstream Free Cash Flow and Total Free Cash Flow). These non-GAAP financial measures are not measures of financial performance prepared or presented in accordance with GAAP and may exclude items that are significant in understanding and assessing our financial results. Therefore, these measures should not be considered in isolation, and users of any such information should not place undue reliance thereon. See the Company’s website, www.rileypermian.com, for the descriptions and reconciliations of non-GAAP measures presented in this presentation to the most directly comparable financial measures calculated in accordance with GAAP. Oil & Gas Reserves The SEC generally permits oil and natural gas companies, in filings made with the SEC, to disclose proved reserves, which are reserve estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions, and certain probable and possible reserves that meet the SEC’s definitions for such terms. In this presentation, Riley Permian may use the terms “resource potential,” “resource play,” “estimated ultimate recovery,” or “EURs,” “type curve” and “standardized measure,” each of which the SEC guidelines restrict from being included in filings with the SEC without strict compliance with SEC definitions. These terms refer to Riley Permian’s internal estimates of unbooked hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques. “Resource potential” is used by Riley Permian to refer to the estimated quantities of hydrocarbons that may be added to proved reserves, largely from a specified resource play potentially supporting numerous drilling locations. A “resource play” is a term used by Riley Permian to describe an accumulation of hydrocarbons known to exist over a large areal expanse and/or thick vertical section potentially supporting numerous drilling locations, which, when compared to a conventional play, typically has a lower geological and/or commercial development risk. “EURs” are based on Riley Permian’s previous operating experience in a given area and publicly available information relating to the operations of producers who are conducting operations in these areas. Unbooked resource potential or “EURs” do not constitute reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or SEC rules and do not include any proved reserves. Actual quantities of reserves that may be ultimately recovered from Riley Permian’s interests may differ substantially from those presented herein. Factors affecting ultimate recovery include the scope of Riley Permian’s ongoing drilling program, which will be directly affected by the availability of capital, decreases in oil, natural gas liquids and natural gas prices, well spacing, drilling and production costs, availability and cost of drilling services and equipment, lease expirations, transportation constraints, regulatory approvals, negative revisions to reserve estimates and other factors, as well as actual drilling results, including geological and mechanical factors affecting recovery rates. “EURs” from reserves may change significantly as development of Riley Permian’s core assets provides additional data. In addition, Riley Permian’s production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price declines or drilling cost increases. “Type curve” refers to a production profile of a well, or a particular category of wells, for a specific play and/or area. Forward-Looking Statements
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3 Riley Permian Overview Riley Permian is a growth-oriented upstream company operating in the Northwest Shelf of Texas and New Mexico, with infrastructure projects that complement our operations Applying modern horizontal drilling and completion techniques to conventional, oil-saturated and liquids- rich formations Returning excess capital to shareholders through dividends(1), share repurchases and debt reduction Prioritizing long-term value creation and resilience through commodity cycles ~$1.0 B Enterprise Value(2) 34.3 MBoe/d 2Q26 Daily Equivalent Production 4.7% Dividend Yield(1)(2) 1.0x LTM Leverage(4) ~320+ Development Locations(5) 17% Insider Ownership(3) Riley Permian by the Numbers (1) Future dividends subject to approval by the Board of Directors (2) Enterprise Value and Dividend Yield based on share price and shares outstanding as of 8/3/26, debt balance and cash balance as of 6/30/26 (3) Based on SEC filings. Insiders include Yorktown (including direct fund entities and Riley Exploration Group LLC), Management, Directors & Other Unvested (4) Leverage calculated as Debt as of 6/30/26 divided by Last Twelve Months Adjusted EBITDAX as of 6/30/26 (5) Company prepared estimates; Data as of 12/31/25 (6) A non-GAAP financial measure as defined and reconciled in the supplemental financial tables available on the Company’s website at www.rileypermian.com Founded in 2016 and achieved public listing in 2021 via reverse merger Pursuing strategic acquisitions: Three acquisitions in New Mexico since 2023 $271 MM LTM Adjusted EBITDAX(6) 62% 2Q26 % Oil Production 21.2 MBbls/d 2Q26 Daily Oil Production
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4 15.8 5.4 24.0 10.3 Riley Permian Asset Overview (1) Company prepared estimates; Data as of 12/31/25 (2) Represents net operated producing horizontal wells as of 12/31/25 Riley Permian operates in the Northwest Shelf of the Permian Basin in Yoakum County, TX and Eddy County, NM Champions Field – Yoakum County, TX Primary Formation Target: ▪ San Andres Net Acres (% HBP)(1): ▪ ~31,000 Net Acres (89% HBP) Net Operated Hz Wells(2): ▪ 117 Undeveloped Net Locations(1): ▪ 100+ Red Lake Field – Eddy County, NM Primary Formation Targets: ▪ Blinebry and Paddock (Yeso) Net Acres (% HBP)(1): ▪ ~64,000 Net Acres (97% HBP) Net Operated Hz Wells(2): ▪ 56 Undeveloped Net Locations(1): ▪ 220+ Yoakum Co. Delaware Basin Yeso Trend Central Basin Platform Eddy Co. N E W M E X I C O T E X A S Red Lake Acquisitions: Pecos (2023) Undisclosed Seller (2024) Silverback (2025) Red Lake Champions Northwest Shelf 30 MilesTexasNew Mexico 2Q26 Total Prod. 34.3 MBoe/d 2Q26 Oil Prod. 21.2 MBbls/d Net Locations(1) +320 Net Locs.
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5 20 40 60 12 24 36 48 60 Cumulative Oil Production Months from First Production 1 10 100 12 24 36 48 60 Average Daily Production Rate Months from First Production Riley Permian Has a Deep, High Value Inventory Base Oil Production Rates over Time Bbls/d per 1,000’ of Lateral Length Oil Production Rates Over Time(1) Bbls/d per 1,000’ of Lateral Length Wells to date have experienced lower relative declines versus Midland and Delaware Basin wells Cumulative Oil Prod. Over Time(1) Bbls Produced per Foot of Lateral Length Wells to date have outperformed Midland and Delaware Basin wells on a 5-year basis Riley Permian Midland Delaware Net Locations by DROI(2)(3) Net Undeveloped Location Count >1.0x DROI Champions Red Lake 300+ high, cash-on-cash return, undeveloped drilling locations (1) Riley Permian, Midland Basin and Delaware Basin production characteristics are a composite of horizontal wells with first production from 2019-2025. Data sourced from Enverus (2) DROI refers to discounted return on investment, which is defined as the present value at a 10% discount rate of future net cashflows excluding capital expenditures divided by the net capital expenditures associated with the development of a horizontal well. Cash flows for DROI of undeveloped locations calculated using strip as of 12/31/25 (3) Inventory data excludes locations with <1.0x DROI Riley Permian wells benefit from high production rates, shallow declines and low well costs 0 100 200 300 400 1.0x-2.0x 2.0x-3.0x >3.0x Total Net Undeveloped Locations Discounted Return on Investment (x)
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6 Track Record of Growth on a Per Share Basis (1) Represents total production volumes divided by average basic shares outstanding for the period T otal Production per Share(1) Barrels of Oil Equivalent per 1,000 Shares
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7 Track Record of Returning Capital to Shareholders Notes: Dividend Yield based on share price as of 8/3/26. Future dividends subject to approval by the Board of Directors. On July 15th, Riley announced 2Q dividend to be paid on August 12th History of paying a fixed dividend every quarter as a public company ▪ Track record of raising dividend annually ▪ 4.7% current dividend yield Share Repurchases ▪ Announced $100MM share repurchase authorization in December 2025 ▪ Repurchased 177K shares of stock year-to-date at a weighted average price of $27.61 per share for a total of $5MM Debt Reduction ▪ Value accrues directly to equity holders 1 2 3
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8 Notes: The non-GAAP financial measures include Adjusted EBITDAX, Total Free Cash Flow, which can be defined in the supplemental financial tables available on the company’s website at www.rileypermian.com. Accrual based capex exclude the impact of acquisitions and contributions to equity method investments (Power JV). LTM Leverage calculated as Debt as of 6/30/26 divided by Last Twelve Months Adjusted EBITDAX as of 6/30/26. Last Twelve Months (LTM) represents a sum of 7/1/25 through 6/30/26 for select metrics. Future dividends subject to approval by the Board of Directors 2Q26 Financial Highlights T otal Daily Production Daily Oil Production Adjusted EBITDAX T otal Accrual Capex 34.3 MBoe/d 21.2 MBbls/d T otal Free Cash Flow Return of Capital (Dividends + Buybacks) $80 $MM $87 $MM $6 $MM $10 $MM Key Results 2Q26 2Q26 Highlights Completion activity and wells turned to sales focused in TX in 2Q26 ▪ Texas: 11.9 net wells drilled, 17.3 net wells completed and 13.9 net wells turned to sales ▪ New Mexico: 8.0 net wells drilled, no wells completed or turned to sales Total production and oil production +41% YoY and +40% YoY , respectively Incurred $87MM of accrual basis capital expenditures (with $68MM on a cash basis) ▪ Accrual Capex composed of $71MM in upstream capex and $16MM for infrastructure and other ▪ Invested $3MM in our power-focused joint venture, RPC Power Reported $64MM of Operating Cash Flow or $75MM before changes in working capital ▪ Generated $6MM of Total Free Cash Flow Returned $10MM to shareholders through dividends and share repurchases ▪ Paid cash dividend of $0.40 per share, for a total of $9MM; Declared $0.40 dividend to be paid in August ▪ Repurchased 25K shares of common stock at a weighted average price of $34.13 for a total of $1MM Debt increased by $26MM with a quarter-end debt-to-LTM Adjusted EBITDAX ratio of 1.0x ▪ Combined principal value of debt of $273MM at quarter-end First merchant power site of RPC Power joint venture has begun commercial operations, and the second site is in final stage of ERCOT commissioning
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9 Downtime Due to Midstream Constraints Impacted Volumes Impact of Third-Party Midstream Disruptions on Second Quarter Production Volumes ▪ Third-party midstream disruptions in April and May during the second quarter , resulted in periodic production curtailments in New Mexico ▪ Disruptions reduced second quarter production by approximately 1.9(1) MBbls/d ▪ Champions activity and recent workover projects offset curtailed volumes ▪ In December of 2025 we contracted with T arga Resources to construct new gathering and high-pressure trunkline infrastructure in New Mexico to mitigate midstream constraints of the nature experienced during the second quarter − In-service date is currently expected to occur in the fourth quarter of 2026 Total Oil Production (MBbls/d) (1) Based on Company estimates TX NM NM Shut-in 3Q-26 Guidance Midpoint (1) (1) (1)
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10 (20%) 0% 20% 40% 60% 80% 100% - 500 1,000 1,500 2,000 2,500 3,000 Jan-25 Feb-25 Mar-25 Apr-25 May-25 Jun-25 Jul-25 Aug-25 Sep-25 Oct-25 Nov-25 Dec-25 Jan-26 Feb-26 Mar-26 Apr-26 May-26 Jun-26 % of Actual Above Underwriting Net Oil Production (Bbls/d) Underwritten Volumes Actual Volumes % of Actual Above Underwriting $500 $350 $335 $275 $66 2022 2023 2024 2025 1H '26 Approx. Avg. Cost of Cleanout AFEs Workover Projects Provide Low-Cost Incremental Production Production at Silverback Asset Nearly Double Underwriting Forecast (1) Expense and volume estimates for workover projects presented on a gross basis ▪ Production has increased significantly at Silverback asset without drilling any new wells by applying fit-for-purpose artificial lift designs, deeper pump installations and targeted cleanouts ▪ Approximately 85% of the identified optimization work at Silverback asset has been completed, however similar strategies will be applied across the broader New Mexico portfolio to arrest decline and maximize asset value ▪ Riley Permian incurred approximately $11 million of workover expense, included in lease operating expense, during the second quarter of 2026 compared to approximately $8 million in the first quarter ▪ Approximately $2.3(1) million of second-quarter workover spending was associated with production enhancement and optimization projects ▪ These projects are expected to support approximately 700(1) Bbls/d of incremental oil production, representing a low-cost source of production growth Significant Reduction in Champions Cleanout Expenses Workovers Providing Low-Cost Barrels ▪ Replaced traditional cleanouts with surface acidizing and scale inhibitor treatments, reducing costs by approximately 75% year-over-year while achieving similar uplift results ▪ Six-well April 2026 campaign generated 230 Bbls/d of oil above forecast in Q2, demonstrating the effectiveness and scalability of the approach $ in thousands Closed on Silverback Acquisition on 7/1/26
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11 3Q 2026 and Updated Full-Year 2026 Guidance (1) Accrual (activity-based) investing expenditures before acquisitions Q3 2026 Full-Year 2026 Metric Guidance Guidance Activity and Production Net Operated Well Activity Drilled # 4.9 - 6.9 51.6 - 53.6 Completed # 8.2 - 10.2 41.1 - 43.1 Turned to Sales # 15.2 - 17.2 42.8 - 44.8 Non-Operated, Net # 1.9 - 2.9 1.9 - 2.9 Net Production Oil MBbls/d 25.1 - 26.1 22.5 - 23.5 Total Equivalent MBoe/d 40.5 - 41.5 37.5 - 38.5 Capital Expenditures and Investments(1) Upstream $MM $46 - $52 $189 - $195 Infrastructure and Other $MM $7 - $13 $41 - $47 Total Capital Expenditures $MM $53 - $65 $230 - $242 Power JV Investment $MM $2 $9 - $10 Total Investments $MM $55 - $67 $239 - $252 Operating and Corporate Costs Lease Operating Expenses $/Boe $8.50 - $9.50 Production and Ad Valorem Taxes % of Revenue 7.5% - 8.5% Administrative Costs $/Boe $2.25 - $2.75
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12 Adjusted EBITDAX ($MM)(1) T otal Free Cash Flow ($MM)(1) Full-Year 2026 Oil Price Sensitivities Estimates Based on Midpoint of Guidance Note: Forecasted metrics based on management estimates and midpoint 2026 guidance. Price sensitivity for WTI uses actual prices through July 2026 and the respective flat oil price case thereafter. Each case uses NYMEX forward monthly pricing as of 7/28/26 for Henry Hub and Waha basis differentials. Realized NGL prices based on management estimates. Includes the impact of hedges. (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 $0 $25 $50 $75 $100 $125 $60 $70 $80 $90 2H26 WTI ($ / Bbl) $0 $100 $200 $300 $400 $60 $70 $80 $90 2H26 WTI ($ / Bbl)
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13 Appendix
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14 $MM REPX Capitalization and Leverage Debt Maturity Profile(3)(4) Capitalization and Debt Maturity Profile (1) Leverage calculated as Debt as of 6/30/26 divided by Last Twelve Months Adjusted EBITDAX as of 6/30/26 (2) Liquidity consists of cash of $21MM, and undrawn credit facility of $262MM as of 6/30/26 (3) RBL maturity will be January 2028 if Senior Notes are still outstanding; otherwise final maturity will occur in December 2028. In May, our Borrowing Base increased to $425MM with an Elected Commitment of $400MM. RBL Utilization of $138MM as of 6/30/26 (4) Current principal amount for Senior Unsecured Notes is $135MM; scheduled amortization reduces current principal by $5MM/quarter $400MM Elected Commitments(3) Sr. Notes (scheduled qrtly pmts) Sr. Notes (due at maturity) RBL utilization RBL availability MM, except share price Total Common Stock Outstanding (8/3/26) 22.2 Share Price (8/3/26) $34.13 Market Capitalization $756 Plus: Total Debt $273 Less: Cash $21 Enterprise Value $1,008 LTM Leverage (1) 1.0x LTM Adjusted EBITDAX $271 Elected Commitment $400 Liquidity(2) $283 $5 $5 $5 $5 $5 $5 $5 $138 $262 $100 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 2026 2027 2028
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15 Equity Ownership Equity Ownership and Research Analyst Coverage Note: Based on SEC filings (1) Insiders include Yorktown, Management, Board of Directors, and other unvested shares (2) Includes affiliated entity holdings aggregated from Form 4 filings. Excludes amounts held directly by Yorktown individuals included in Management, Directors & Other Unvested (3) Includes 1.2MM of unvested and contingent stock awards across all employees and directors, including 414K of performance-based awards at a maximum payout potential of 200%, as required by GAAP; actual payout could range from 0% to 200%, at which time the number of actual shares outstanding will be adjusted Research Analyst Coverage Energy Prospectus Daniel Steffens dmsteffens@comcast.net Roth Capital Nick Pope npope@roth.com Texas Capital Derrick Whitfield derrick.whitfield@texascapital.com Truist Gabe Daoud Gabe.Daoud@truist.com Tuohy Brothers Noel Parks nparks@tuohybrothers.com Water Tower Jeff Robertson jeff@watertowerresearch.com William Blair Neal Dingmann ndingmann@williamblair.com Shares (MM) Ownership % ◉ Yorktown Energy Partners(2) 2.09 9.4% ◉ Mgmt, Directors & Other Unvested Awards(3) 1.70 7.7% 3.79 17.1% ◉ Balmon Investments(2) 2.24 10.1% ◉ Estimated Public Float 16.12 72.8% 22.15 100.0% >5% Holders & Insiders as of 8/3/26(1) Total Insider Ownership Total 9% 8% 10% 73%
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16 Facility Principal Amount Outstanding at 6/30/26 Elected Commitment at 6/30/26 Annual Interest Rate Amortization Final Maturity Sr. Secured Credit Facility $138MM $400MM Term SOFR + 2.75% – 3.75%; Margin of 3.00% at 6/30/26 None; Company intends to periodically pay down balance with excess cash flow December 2028(2) Sr. Unsecured Notes $135MM NA 10.5% $5MM/quarter April 2028 Total $273MM Debt Summary 33% of principal value of debt at 6/30/26 is hedged through April ’27; SOFR swaps in place for $45MM(1) of notional value through April ’27 66% of the principal value of debt at 6/30/26 is fixed rate or hedged absent any paydown on the credit facility through April ’27 1 2 (1) 1-Month term weighted average SOFR Fixed Rate of 3.90% (2) Maturity will be January 2028 if Senior Unsecured Notes are then outstanding
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17 Hedging Summary Positions as of 8/3/26 Note: Q3 2026 derivative positions shown include 2026 contracts, some which have settled as of 8/3/26 2026 2027 2028 3Q 4Q FY 2026 1Q 2Q 3Q 4Q FY 2027 1Q 2Q Crude Oil (WTI) Fixed Swap - Volume Bbls 860,000 820,000 3,456,000 725,000 650,000 630,000 605,000 2,610,000 330,000 0 Weighted Average Price $/Bbl $61.65 $61.42 $61.81 $61.48 $61.68 $61.38 $61.62 $61.54 $70.18 $0.00 Collar - Volume Bbls 570,000 550,000 2,177,000 475,000 537,000 490,000 315,000 1,817,000 270,000 90,000 Weighted Average Floor Price $/Bbl $58.25 $57.75 $58.58 $57.15 $55.84 $54.22 $57.38 $56.01 $56.67 $60.00 Weighted Average Ceiling Price $/Bbl $72.66 $69.59 $73.18 $66.42 $67.97 $69.43 $72.26 $68.70 $75.77 $80.65 Total Oil Volumes Bbls 1,430,000 1,370,000 5,633,000 1,200,000 1,187,000 1,120,000 920,000 4,427,000 600,000 90,000 Downside Weighted Average Price $/Bbl $60.30 $59.95 $60.56 $59.77 $59.04 $58.25 $60.17 $59.27 $64.10 $60.00 Natural Gas (HH) Fixed Swap - Volume MMBtu 300,000 500,000 2,255,000 600,000 0 0 0 600,000 0 0 Weighted Average Price $/MMBtu $3.59 $4.07 $3.87 $4.19 $0.00 $0.00 $0.00 $4.19 $0.00 $0.00 Collar - Volume MMBtu 900,000 600,000 2,625,000 450,000 0 0 0 450,000 0 0 Weighted Average Floor Price $/MMBtu $3.05 $3.43 $3.19 $3.80 $0.00 $0.00 $0.00 $3.80 $0.00 $0.00 Weighted Average Ceiling Price $/MMBtu $3.74 $4.79 $4.03 $5.84 $0.00 $0.00 $0.00 $5.84 $0.00 $0.00 Total Natural Gas Volumes MMBtu 1,200,000 1,100,000 4,880,000 1,050,000 0 0 0 1,050,000 0 0 Downside Weighted Average Price $/MMBtu $3.19 $3.72 $3.51 $4.02 $0.00 $0.00 $0.00 $4.02 $0.00 $0.00 Waha Basis Waha Basis Swap Volume MMBtu 1,250,000 3,450,000 5,600,000 3,150,000 3,150,000 3,150,000 3,150,000 12,600,000 1,800,000 0 Weighted Average Price $/MMBtu ($1.65) ($1.58) ($1.69) ($0.94) ($0.95) ($0.95) ($0.95) ($0.95) ($1.01) $0.00