Permian Resources Announces Strong Fourth Quarter 2024 Results and Provides Full Year 2025 Plan with Increased Capital Efficiency MIDLAND, Texas – February 25, 2025 (BUSINESS WIRE) -- Permian Resources Corporation (“Permian Resources” or the “Company”) (NYSE: PR) today announced its fourth quarter and full year 2024 financial and operational results and 2025 operational plans. Fourth Quarter 2024 Financial and Operational Highlights • Reported crude oil and total average production of 171.3 MBbls/d and 368.4 MBoe/d • Announced cash capital expenditures of $504 million, cash provided by operating activities of $872 million and adjusted free cash flow 1 of $400 million • Reduced D&C costs to ~$775 per lateral foot • Announced the divestiture of Barilla Draw natural gas and oil gathering systems for $180 million • Added ~2,100 net acres through >90 grassroots transactions for ~$3,900 per net acre, demonstrating continued ground game success • Declared base dividend of $0.15 per share, representing 4.3% yield • Maintained strong balance sheet with leverage of 0.95x and total liquidity of ~$3.0 billion Full Year 2024 Financial and Operational Highlights • Reported crude oil and total average production of 159.2 MBbls/d and 343.5 MBoe/d, an increase of 63% and 77% compared to the prior year • Generated cash provided by operating activities of $3.4 billion and adjusted free cash flow 1 of $1.4 billion • Realized significant operational efficiency gains, resulting in reduced cycle times and lower well costs ◦ Reduced D&C per foot costs by 14% year-over-year • Replaced >100% of drilled inventory through accretive M&A for second consecutive year • Increased quarterly base dividend from $0.05 to $0.15 per share 2025 Financial and Operational Plan • Announced highly capital efficient operating plan underpinned by consistent well performance, lower well costs and peer leading controllable cash costs ◦ Crude oil and total average production guidance of 170 to 175 MBbls/d and 360 to 380 MBoe/d ▪ Represents ~8% higher annual production compared to full year 2024 ◦ Total cash capital expenditure budget of $1.9 to $2.1 billion ◦ Total controllable cash costs of $7.25 to $8.25 per Boe Management Commentary “Permian Resources had another outstanding year in 2024, and we could not be more proud of our team for everything they accomplished last year,” said Will Hickey, Co-CEO of Permian Resources. “With our low cost structure serving as the foundation, Permian Resources delivered peer leading per share growth during 2024, which helped generate a superior total return for our shareholders.” “We are excited to announce our 2025 plan, which is highlighted by 8% higher annual production and no change to our approximately $2 billion capital budget from 2024. This improved year-over-year capital efficiency is driven by our consistent development approach and significantly lower cost structure,” said James Walter, Co-CEO of Permian Resources. “Most importantly, our 2025 plan allows us to generate more free cash flow than 2024, maximizing value for shareholders.” Financial and Operational Results Permian Resources continued the efficient development of its core Delaware Basin acreage position in the fourth quarter, while fully integrating the Barilla Draw bolt-on acquisition. During the quarter, average daily crude oil production was 171,274 Bbls/d, a 7% increase compared to the prior quarter. Reported natural gas and NGL volumes were 634,546 Mcf/d and 91,382 Bbls/d, respectively. Fourth quarter total production was 368,414 Boe/d. Total cash capital expenditures (“capex”) for the fourth quarter were $504 million. The Company continues to reduce well costs on a per lateral foot basis. For the fourth quarter, drilling and completion costs per lateral foot were approximately $775, or a 3% reduction from the previous quarter. Realized prices for the quarter were $69.66 per barrel of oil, $0.87 per Mcf of natural gas and $24.05 per barrel of NGLs. During the quarter, total controllable cash costs (LOE, GP&T and cash G&A) were $7.84 per Boe, an $0.11 per Boe reduction from the prior quarter. Fourth quarter LOE was $5.42 per Boe, GP&T was $1.49 per Boe and cash G&A was $0.93 per Boe. For the fourth quarter, Permian Resources generated net cash provided by operating activities of $872 million, adjusted operating cash flow 1 of $904 million and adjusted free cash flow 1 of $400 million. Adjusted diluted shares 1 outstanding were 847.1 million for the three months ended December 31, 2024. Permian Resources continues to maintain a strong financial position and low leverage profile. The Company further strengthened its balance sheet by increasing the amount of cash on hand by over $200 million quarter-over-quarter to $479 million, as of December 31, 2024. Permian Resources’ revolving credit facility remained undrawn at year-end. Total liquidity was $3.0 billion. Net debt-to-LQA EBITDAX 1 at December 31, 2024 was 0.95x. 2025 Operational Plan and Targets Permian Resources’ 2025 operational plan is focused on maximizing free cash flow for its investors and delivering better year-over-year capital efficiency through the combination of consistent well productivity and considerably lower costs. Assuming planned activity levels and current commodity prices, the Company expects its full year oil and total production to average approximately 170 to 175 MBbls/d and 360 to 380 MBoe/d, respectively. The estimated fiscal year 2025 cash capex budget is approximately $1.9 billion to $2.1 billion, with approximately 80% allocated to drilling and completions with the remaining 20% allocated to facilities, infrastructure, capital workover and non-operated capex. Notably, this represents annual oil and total production growth of approximately 8%, while maintaining a similar capital budget year-over-year. Permian Resources expects to turn-in-line (“TIL”) approximately 285 gross wells, with an average working interest of approximately 75% and 8/8ths net revenue interest of approximately 79%. The Company also expects its average completed lateral length during 2025 to be approximately 10,000 feet, an increase of 700 feet from the previous year. Through realized efficiency gains, the Company’s capital budget is further supported by an approximately 8% reduction in D&C costs per foot compared to 2024. Similar to the previous year, Permian Resources anticipates that approximately 65% of its 2025 operating activity will be directed towards New Mexico and approximately 30% towards the Texas Delaware Basin, with the remaining portion to be allocated to its Midland Basin position. Through its continued focus on remaining the Delaware Basin’s low-cost leader, Permian Resources anticipates total controllable cash costs of $7.25 to $8.25 per Boe in 2025. The mid-point represents an approximately $0.10 per Boe reduction compared to Permian Resources’ 2024 total controllable cash costs, demonstrating the Company’s cost leadership and ability to successfully integrate acquired assets. Specifically, controllable cash costs consist of approximately $5.55 per Boe for LOE, $1.30 per Boe for GP&T expense and $0.90 per Boe for cash G&A. The Company expects its oil realizations to average 98% to 100% of WTI during 2025. Permian Resources estimates its average realized revenue from natural gas to be approximately $0.30 to $0.50 per Mcf less than Waha Hub pricing and its NGLs to be approximately 27% to 30% of WTI. (For a detailed table summarizing Permian Resources’ 2025 operational and financial guidance, please see the Appendix of this press release.) Shareholder Returns Permian Resources announced today that its Board of Directors (the “Board”) declared the Company’s first quarter 2025 base dividend of $0.15 per share of Class A common stock, or $0.60 per share on an annualized basis. The base dividend is payable on March 31, 2025 to shareholders of record as of March 17, 2025. The Company’s base dividend represents an annualized yield of 4.3% as of February 24, 2025. Year-End 2024 Proved Reserves Permian Resources reported year-end 2024 total proved reserves of 1,027 MMBoe compared to 925 MMBoe at prior year-end. At year-end 2024, proved reserves consisted of 45% oil, 30% natural gas and 25% natural gas liquids. Proved developed reserves were 746 MMBoe (73% of total proved reserves) at December 31, 2024. Netherland Sewell & Associates, Inc., an independent reserve engineering firm, prepared Permian Resources’ year-end reserves estimates for the year ended December 31, 2024. Recent Events During the first quarter of 2025, Permian Resources closed the non-core divestiture of its oil and gas gathering systems in Reeves County, Texas for gross proceeds of $180 million, further enhancing the returns associated with its 2024 acquisition program. Additionally, the Company utilized cash on hand to partially redeem $175 million in aggregate principal amount of its 9.875% Senior Notes due 2031. Annual Report on Form 10-K Permian Resources’ financial statements and related footnotes will be available in its Annual Report on Form 10-K for the year ended December 31, 2024, which is expected to be filed with the Securities and Exchange Commission (“SEC”) on February 26, 2025. Conference Call and Webcast Permian Resources will host an investor conference call on Wednesday, February 26, 2025 at 9:00 a.m. Central (10:00 a.m. Eastern) to discuss fourth quarter and full year 2024 operating and financial results. Interested parties may join the call by visiting Permian Resources’ website at www.permianres.com and clicking on the webcast link or by dialing (800) 549-8228 (Conference ID: 75050) at least 15 minutes prior to the start of the call. A replay of the call will be available on the Company’s website or by phone at (888) 660-6264 (Passcode: 75050) for a 14-day period following the call. About Permian Resources Headquartered in Midland, Texas, Permian Resources is an independent oil and natural gas company focused on the responsible acquisition, optimization and development of high-return oil and natural gas properties. The Company’s assets and operations are concentrated in the core of the Delaware Basin, making it the second largest Permian Basin pure-play E&P. For more information, please visit www.permianres.com. Cautionary Note Regarding Forward-Looking Statements The information in this press release includes “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 included in this press release, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this press release, the words “could,” “may,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “goal,” “plan,” “target” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on management’s current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. Forward-looking statements may include statements about: • volatility of oil, natural gas and NGL prices or a prolonged period of low oil, natural gas or NGL prices and the effects of actions by, or disputes among or between, members of the Organization of Petroleum Exporting Countries (“OPEC”), such as Saudi Arabia, and other oil and natural gas producing countries, such as Russia, with respect to production levels or other matters related to the price of oil, natural gas and NGLs; • political and economic conditions in or affecting other producing regions or countries, including the Middle East, Russia, Eastern Europe, Africa and South America; • our business strategy and future drilling plans; • our reserves and our ability to replace the reserves we produce through drilling and property acquisitions; • our drilling prospects, inventories, projects and programs; • our financial strategy, return of capital program, leverage, liquidity and capital required for our development program; • our realized oil, natural gas and NGL prices; • the timing and amount of our future production of oil, natural gas and NGLs; • our ability to identify, complete and effectively integrate acquisitions of properties or businesses; • our hedging strategy and results; • our competition; • our ability to obtain permits and governmental approvals; • our compliance with government regulations, including those related to climate change as well as environmental, health and safety regulations and liabilities thereunder; • our pending legal or environmental matters; • the marketing and transportation of our oil, natural gas and NGLs; • our leasehold or business acquisitions; • costs of developing or operating our properties; • our anticipated rate of return; • general economic conditions; • weather conditions in the areas where we operate; • credit markets; • our ability to make dividends, distributions and share repurchases; • uncertainty regarding our future operating results; • our plans, objectives, expectations and intentions contained in this press release that are not historical; and • the other factors described in our most recent Annual Report on Form 10-K, and any updates to those factors set forth in our subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K. We caution you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond our control, incident to the exploration for and development, production, gathering and sale of oil, natural gas and NGLs. Factors which could cause our actual results to differ materially from the results contemplated by forward-looking statements include, but are not limited to: • commodity price volatility (including regional basis differentials); • uncertainty inherent in estimating oil, natural gas and NGL reserves, including the impact of commodity price declines on the economic producibility of such reserves, and in projecting future rates of production; • geographic concentration of our operations; • lack of availability of drilling and production equipment and services; • lack of transportation and storage capacity as a result of oversupply, government regulations or other factors; • risks related to our recent acquisitions, including the risk that we may fail to integrate such acquisitions on the terms and timing currently contemplated, or at all, and/or to realize our strategy and plans to achieve the expected benefits of such acquisitions; • competition in the oil and natural gas industry for assets, materials, qualified personnel and capital; • drilling and other operating risks; • environmental and climate related risks, including seasonal weather conditions; • regulatory changes, including those that may result from the U.S. Supreme Court’s decision overturning the Chevron deference doctrine and that may impact environmental, energy, and natural resources regulation; • the possibility that the industry in which we operate may be subject to new or volatile local, state, and federal or legislative actions (including additional taxes and changes in environmental, health, and safety regulation and regulations related to climate change) as a result of developing national and/or global efforts to address climate change; • restrictions on the use of water, including limits on the use of produced water and potential restrictions on the availability to water disposal facilities; • availability to cash flow and access to capital; • inflation; • changes in our credit ratings or adverse changes in interest rates; • changes in the financial strength of counterparties to our credit agreement and hedging contracts; • the timing of development expenditures; • political and economic conditions and events in foreign oil and natural gas producing countries, including embargoes, continued hostilities in the Middle East and other sustained military campaigns, including the conflict in Israel and its surrounding areas, the war in Ukraine and associated economic sanctions on Russia, conditions in South America, Central America, China and Russia, and acts of terrorism or sabotage; • changes in local, regional, national, and international economic conditions; • security threats, including evolving cybersecurity risks such as those involving unauthorized access, denial-of-service attacks, third-party service provider failures, malicious software, data privacy breaches by employees, insiders or other with authorized access, cyber or phishing-attacks, ransomware, social engineering, physical breaches or other actions; and • other risks described in our filings with the SEC. Reserve engineering is a process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact way. The accuracy of any oil and gas reserve estimate depends on the quality of available data, the interpretation of such data, and price and cost assumptions made by reserve engineers. In addition, the results of drilling, testing and production activities may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of oil and natural gas that are ultimately recovered. Should one or more of the risks or uncertainties described in this press release occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements, expressed or implied, included in this press release are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this press release. 1) Adjusted Operating Cash Flow, Adjusted Free Cash Flow, Adjusted Diluted Shares and Net Debt-to-LQA EBITDAX are non-GAAP financial measures. See “Non-GAAP Financial Measures” included within the Appendix of this press release for related disclosures and reconciliations to the most directly comparable financial measures calculated and presented in accordance with GAAP. Contacts: Hays Mabry – Vice President, Investor Relations (832) 240-3265 ir@permianres.com SOURCE Permian Resources Corporation Details of our 2025 operational and financial guidance are presented below: 2025 FY Guidance Net average daily production (Boe/d) 360,000 — 380,000 Net average daily oil production (Bbls/d) 170,000 — 175,000 Production costs Total controllable cash costs $7.25 — $8.25 Lease operating expenses ($/Boe) ~$5.55 Gathering, processing and transportation expenses ($/Boe) ~$1.30 Cash general and administrative ($/Boe) (1) ~$0.90 Severance and ad valorem taxes (% of revenue) 6.5% — 8.5% Total cash capital expenditure program ($MM) $1,900 — $2,100 Operated drilling program TILs (gross) ~285 Average working interest ~75% Average lateral length (feet) ~10,000 (1) Excludes stock-based compensation. Permian Resources Corporation Operating Highlights Three Months Ended December 31, Year Ended December 31, 2024 2023 2024 2023 Net revenues (in thousands): Oil sales $ 1,097,662 $ 962,720 $ 4,362,965 $ 2,696,777 Natural gas sales (1) 21,591 47,954 240 142,077 NGL sales (2) 176,828 112,012 637,529 282,039 Oil and gas sales $ 1,296,081 $ 1,122,686 $ 5,000,734 $ 3,120,893 Average sales prices: Oil (per Bbl) $ 69.66 $ 76.61 $ 74.87 $ 75.84 Effect of derivative settlements on average price (per Bbl) 1.09 0.53 0.03 1.81 Oil including the effects of hedging (per Bbl) $ 70.75 $ 77.14 $ 74.90 $ 77.65 Average NYMEX WTI price for oil (per Bbl) $ 70.28 $ 78.32 $ 75.72 $ 77.62 Oil differential from NYMEX (0.62) (1.71) (0.85) (1.78) Natural gas price excluding the effects of GP&T (per Mcf) (1) $ 0.87 $ 1.50 $ 0.47 $ 1.60 Effect of derivative settlements on average price (per Mcf) 0.34 0.09 0.34 0.29 Natural gas including the effects of hedging (per Mcf) $ 1.21 $ 1.59 $ 0.81 $ 1.89 Average NYMEX Henry Hub price for natural gas (per MMBtu) $ 2.42 $ 2.74 $ 2.24 $ 2.53 Natural gas differential from NYMEX (1.55) (1.24) (1.77) (0.93) NGL price excluding the effects of GP&T (per Bbl) (2) $ 24.05 $ 21.57 $ 23.75 $ 22.83 Net production: Oil (MBbls) 15,757 12,566 58,276 35,560 Natural gas (MMcf) 58,378 44,048 220,900 119,182 NGL (MBbls) 8,407 6,328 30,636 15,569 Total (MBoe) (3) 33,895 26,234 125,730 70,992 Average daily net production: Oil (Bbls/d) 171,274 136,590 159,225 97,424 Natural gas (Mcf/d) 634,546 478,781 603,551 326,525 NGL (Bbls/d) 91,382 68,774 83,706 42,654 Total (Boe/d) (3) 368,414 285,161 343,523 194,499 (1) Natural gas sales for the three months and year ended December 31, 2024 include $29.0 million and $104.1 million, respectively, of gathering, processing and transportation (“GP&T”) costs that are reflected as a reduction to natural gas sales and $18.2 million and $48.9 million for the three months and year ended December 31, 2023, respectively. Natural gas average sales price, however, excludes $0.50 and $0.47 per Mcf of such GP&T charges for the three months and year ended December 31, 2024, respectively, and $0.41 per Mcf for both the three months and year ended December 31, 2023. (2) NGL sales for the three months and year ended December 31, 2024 include $25.3 million and $90.0 million, respectively, of GP&T that are reflected as a reduction to NGL sales and $24.4 million and $73.3 million for the three months and year ended December 31, 2023, respectively. NGL average sales price, however, excludes $3.01 and $2.94 per Bbl of such GP&T charges for the three months and year ended December 31, 2024, respectively, and $3.87 and $4.71 per Bbl for the three months and year ended December 31, 2023, respectively. (3) Calculated by converting natural gas to oil equivalent barrels at a ratio of six Mcf of natural gas to one Boe. Permian Resources Corporation Operating Expenses Three Months Ended December 31, Year Ended December 31, 2024 2023 2024 2023 Operating costs (in thousands): Lease operating expenses $ 183,575 $ 130,439 $ 685,172 $ 373,772 Severance and ad valorem taxes 96,947 84,384 377,731 240,762 Gathering, processing, and transportation expense 50,582 31,316 183,602 89,282 Operating cost metrics: Lease operating expenses (per Boe) $ 5.42 $ 4.97 $ 5.45 $ 5.26 Severance and ad valorem taxes (% of revenue) 7.5 % 7.5 % 7.6 % 7.7 % Gathering, processing, and transportation expense (per Boe) 1.49 1.19 1.46 1.26 Permian Resources Corporation Consolidated Statements of Operations (in thousands, except per share data) Three Months Ended December 31, Year Ended December 31, 2024 2023 2024 2023 Operating revenues Oil and gas sales $ 1,296,081 $ 1,122,686 $ 5,000,734 $ 3,120,893 Operating expenses Lease operating expenses 183,575 130,439 685,172 373,772 Severance and ad valorem taxes 96,947 84,384 377,731 240,762 Gathering, processing and transportation expenses 50,582 31,316 183,602 89,282 Depreciation, depletion and amortization 486,463 367,427 1,776,673 1,007,576 General and administrative expenses 44,745 39,126 174,630 161,855 Merger and integration expense — 97,260 18,064 125,331 Impairment and abandonment expense 2,128 5,947 9,912 6,681 Exploration and other expenses 6,363 4,669 30,791 19,337 Total operating expenses 870,803 760,568 3,256,575 2,024,596 Net gain (loss) on sale of long-lived assets (66) 82 375 211 Income from operations 425,212 362,200 1,744,534 1,096,508 Other income (expense) Interest expense (76,783) (63,024) (304,756) (177,209) Net gain (loss) on derivative instruments (36,716) 190,684 94,986 114,016 Other income (expense) 6,411 1,648 16,087 2,333 Total other income (expense) (107,088) 129,308 (193,683) (60,860) Income before income taxes 318,124 491,508 1,550,851 1,035,648 Income tax expense (62,645) (78,889) (300,342) (155,945) Net income 255,479 412,619 1,250,509 879,703 Less: Net income attributable to noncontrolling interest (38,829) (157,265) (265,808) (403,397) Net income attributable to Class A Common Stock $ 216,650 $ 255,354 $ 984,701 $ 476,306 Income per share of Class A Common Stock: Basic $ 0.31 $ 0.56 $ 1.54 $ 1.36 Diluted $ 0.29 $ 0.51 $ 1.45 $ 1.24 Weighted average Class A Common Stock outstanding: Basic 702,968 459,593 640,662 349,213 Diluted 746,693 500,919 684,492 389,096 Permian Resources Corporation Consolidated Balance Sheets (in thousands, except share and per share amounts) December 31, 2024 December 31, 2023 ASSETS Current assets Cash and cash equivalents $ 479,343 $ 73,290 Accounts receivable, net 530,452 481,060 Derivative instruments 85,509 70,591 Prepaid and other current assets 26,290 25,451 Total current assets 1,121,594 650,392 Property and equipment Oil and natural gas properties, successful efforts method Unproved properties 1,990,441 2,401,317 Proved properties 18,595,780 15,036,687 Accumulated depreciation, depletion and amortization (5,163,124) (3,401,895) Total oil and natural gas properties, net 15,423,097 14,036,109 Other property and equipment, net 50,381 43,647 Total property and equipment, net 15,473,478 14,079,756 Noncurrent assets Operating lease right-of-use assets 119,703 59,359 Other noncurrent assets 183,125 176,071 TOTAL ASSETS $ 16,897,900 $ 14,965,578 LIABILITIES AND EQUITY Current liabilities Accounts payable and accrued expenses $ 1,198,418 $ 1,167,525 Operating lease liabilities 57,216 33,006 Other current liabilities 71,703 41,022 Total current liabilities 1,327,337 1,241,553 Noncurrent liabilities Long-term debt, net 4,184,233 3,848,781 Asset retirement obligations 148,443 121,417 Deferred income taxes 602,379 422,627 Operating lease liabilities 64,288 28,302 Other noncurrent liabilities 52,701 73,150 Total liabilities 6,379,381 5,735,830 Shareholders’ equity Common stock, $0.0001 par value, 1,500,000,000 shares authorized: Class A: 707,388,380 shares issued and 703,774,082 shares outstanding at December 31, 2024 and 544,610,984 shares issued and 540,789,758 shares outstanding at December 31, 2023 71 54 Class C: 99,599,640 shares issued and outstanding at December 31, 2024 and 230,962,833 shares issued and outstanding at December 31, 2023 10 23 Additional paid-in capital 8,056,552 5,766,881 Retained earnings (accumulated deficit) 1,081,895 569,139 Total shareholders’ equity 9,138,528 6,336,097 Noncontrolling interest 1,379,991 2,893,651 Total equity 10,518,519 9,229,748 TOTAL LIABILITIES AND EQUITY $ 16,897,900 $ 14,965,578 Permian Resources Corporation Consolidated Statements of Cash Flows (in thousands) Year Ended December 31, 2024 2023 Cash flows from operating activities: Net income $ 1,250,509 $ 879,703 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization 1,776,673 1,007,576 Stock-based compensation expense 60,399 78,418 Impairment and abandonment expense 9,912 6,681 Deferred tax expense 299,019 152,383 Net (gain) loss on sale of long-lived assets (375) (211) Non-cash portion of derivative (gain) loss (17,783) (14,606) Amortization of debt issuance costs, discount and premium 6,563 11,326 Loss on extinguishment of debt 8,585 — Changes in operating assets and liabilities: (Increase) decrease in accounts receivable (51,396) 36,336 (Increase) decrease in prepaid and other assets (8,491) (27,267) Increase (decrease) in accounts payable and other liabilities 78,353 83,160 Net cash provided by operating activities 3,411,968 2,213,499 Cash flows from investing activities: Acquisition of oil and natural gas properties, net (1,047,128) (234,288) Drilling and development capital expenditures (2,060,667) (1,524,899) Cash (paid) received for businesses acquired in mergers, net of cash received — 39,832 Purchases of other property and equipment (12,845) (34,483) Contingent considerations received related to divestiture — 60,000 Proceeds from sales of oil and natural gas properties 16,445 115,459 Net cash used in investing activities (3,104,195) (1,578,379) Cash flows from financing activities: Proceeds from equity offering, net 402,211 — Proceeds from borrowings under revolving credit facility 1,965,000 1,950,000 Repayment of borrowings under revolving credit facility (1,965,000) (2,335,000) Repayment of credit facility acquired in mergers — (830,000) Proceeds from issuance of senior notes 1,000,000 997,500 Debt issuance and redemption costs (26,498) (15,169) Redemption of senior notes (656,351) — Proceeds from exercise of stock options 257 534 Share repurchases (61,048) (162,420) Dividends paid (466,915) (141,947) Distributions paid to noncontrolling interest owners (93,950) (94,686) Net cash (used in) provided by financing activities 97,706 (631,188) Net increase (decrease) in cash, cash equivalents and restricted cash 405,479 3,932 Cash, cash equivalents and restricted cash, beginning of period 73,864 69,932 Cash, cash equivalents and restricted cash, end of period $ 479,343 $ 73,864 Reconciliation of cash, cash equivalents and restricted cash presented on the consolidated statements of cash flows for the periods presented: Year Ended December 31, 2024 2023 Cash and cash equivalents $ 479,343 $ 73,290 Restricted cash $ — $ 574 Total cash, cash equivalents and restricted cash $ 479,343 $ 73,864 Non-GAAP Financial Measures In addition to disclosing financial results calculated in accordance with U.S. generally accepted accounting principles (“GAAP”), our earnings release contains non-GAAP financial measures as described below. Adjusted EBITDAX Adjusted EBITDAX is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. We define Adjusted EBITDAX as net income attributable to Class A Common Stock before net income attributable to noncontrolling interest, interest expense, income taxes, depreciation, depletion and amortization, impairment and abandonment expense, non-cash gains or losses on derivatives, stock-based compensation, exploration and other expenses, merger and integration expense, gain/loss from the sale of long-lived assets and non-recurring items. Adjusted EBITDAX is not a measure of net income as determined by GAAP. Our management believes Adjusted EBITDAX is useful as it allows them to more effectively evaluate our operating performance and compare the results of our operations from period to period and against our peers, without regard to our financing methods or capital structure. We exclude the items listed above from net income in arriving at Adjusted EBITDAX because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDAX should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of our operating performance or liquidity. Certain items excluded from Adjusted EBITDAX are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDAX. Our presentation of Adjusted EBITDAX should not be construed as an inference that our results will be unaffected by unusual or nonrecurring items. Our computations of Adjusted EBITDAX may not be comparable to other similarly titled measures of other companies. The following table presents a reconciliation of Adjusted EBITDAX to net income, which is the most directly comparable financial measure calculated and presented in accordance with GAAP: Three Months Ended (in thousands) 12/31/2024 9/30/2024 6/30/2024 3/31/2024 12/31/2023 Adjusted EBITDAX reconciliation to net income: Net income attributable to Class A Common Stock $ 216,650 $ 386,376 $ 235,100 $ 146,575 $ 255,354 Net income attributable to noncontrolling interest 38,829 70,151 73,808 83,020 157,265 Interest expense 76,783 79,934 75,452 72,587 63,024 Income tax expense 62,645 106,468 82,272 48,957 78,889 Depreciation, depletion and amortization 486,463 453,603 426,428 410,179 367,427 Impairment and abandonment expense 2,128 1,380 6,384 20 5,947 Non-cash derivative (gain) loss 73,579 (213,102) (6,734) 128,474 (180,179) Stock-based compensation expense (1) 13,149 13,537 22,463 9,094 8,495 Exploration and other expenses 6,363 6,962 5,978 11,488 4,669 Merger and integration expense — — 6,941 11,123 97,260 (Gain) loss on sale of long-lived assets 66 (329) — (112) (82) Adjusted EBITDAX $ 976,655 $ 904,980 $ 928,092 $ 921,405 $ 858,069 (1) Includes stock-based compensation expense for equity awards related to general and administrative employees only. Stock-based compensation amounts for geographical and geophysical personnel are included within the Exploration and other expenses line item. Net Debt-to-LQA EBITDAX Net debt-to-LQA EBITDAX is a non-GAAP financial measure. We define net debt as long-term debt, net, plus unamortized debt discount and debt issuance costs on our senior notes minus cash and cash equivalents. We define net debt-to-LQA EBITDAX as net debt (defined above) divided by Adjusted EBITDAX (defined and reconciled in the section above) for the three months ended December 31, 2024, on an annualized basis. We refer to this metric to show trends that investors may find useful in understanding our ability to service our debt. This metric is widely used by professional research analysts, including credit analysts, in the valuation and comparison of companies in the oil and gas exploration and production industry. The following table presents a reconciliation of net debt to long-term debt, net and the calculation of net debt-to-LQA EBITDAX for the period presented: (in thousands) December 31, 2024 Long-term debt, net $ 4,184,233 Unamortized debt discount, debt issuance costs and debt premium on senior notes 25,215 Long-term debt 4,209,448 Less: cash and cash equivalents (479,343) Net debt (Non-GAAP) 3,730,105 LQA EBITDAX (1) $ 3,906,620 Net debt-to-LQA EBITDAX 0.95 (1) Represents adjusted EBITDAX (defined and reconciled in the section above) for the three months ended December 31, 2024, on an annualized basis. Adjusted Shares Adjusted basic and diluted weighted average shares outstanding (“Adjusted Basic and Diluted Shares”) are non-GAAP financial measures defined as basic and diluted weighted average shares outstanding adjusted to reflect the weighted average shares of our Class C Common Stock outstanding during the period. Our Adjusted Basic and Diluted Shares provide a comparable per share measurement when presenting results such as adjusted free cash flow and adjusted net income that include the interests of both net income attributable to Class A Common Stock and the net income attributable to our noncontrolling interest. Adjusted Basic and Diluted Shares are used in calculating several metrics that we use as supplemental financial measurements in the evaluation of our business. The following table presents a reconciliation of Adjusted Basic and Diluted Shares to basic and diluted weighted average shares outstanding, which are the most directly comparable financial measure calculated and presented in accordance with GAAP: Three Months Ended December 31, Year Ended December 31, (in thousands) 2024 2023 2024 2023 Basic weighted average shares of Class A Common Stock outstanding 702,968 459,593 640,662 349,213 Weighted average shares of Class C Common Stock 100,401 244,039 144,566 248,511 Adjusted basic weighted average shares outstanding 803,369 703,632 785,228 597,724 Basic weighted average shares of Class A Common Stock outstanding 702,968 459,593 640,662 349,213 Add: Dilutive effects of Convertible Senior Notes 29,408 28,090 29,408 27,710 Add: Dilutive effects of equity awards 14,317 13,236 14,422 12,173 Diluted weighted average shares of Class A Common Stock outstanding 746,693 500,919 684,492 389,096 Weighted average shares of Class C Common Stock 100,401 244,039 144,566 248,511 Adjusted diluted weighted average shares outstanding 847,094 744,958 829,058 637,607 Adjusted Operating Cash Flow and Adjusted Free Cash Flow Adjusted operating cash flow and adjusted free cash flow are supplemental non-GAAP financial measures used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. We define adjusted operating cash flow as net cash provided by operating activities adjusted to remove changes in working capital, merger and integration and other non-recurring charges, and estimated tax distributions to our non-controlling interest owners. Adjusted operating cash flows is reduced by total cash capital expenditures to arrive at adjusted free cash flows. Our management believes adjusted operating cash flow and adjusted free cash flow are useful indicators of the Company’s ability to internally fund its future exploration and development activities, to service its existing level of indebtedness or incur additional debt, without regard to the timing of settlement of either operating assets and liabilities, its merger and integration and other non-recurring costs or estimated tax distributions to noncontrolling interest owners after funding its capital expenditures paid for the period. The Company believes that these measures, as so adjusted, present meaningful indicators of the Company’s actual sources and uses of capital associated with its operations conducted during the applicable period. Our computation of adjusted operating cash flow and adjusted free cash flow may not be comparable to other similarly titled measures of other companies. Adjusted operating cash flow and adjusted free cash flow should not be considered as alternatives to, or more meaningful than, net cash provided by operating activities as determined in accordance with GAAP or as indicators of our operating performance or liquidity. Adjusted operating cash flow and adjusted free cash flow are not financial measures that are determined in accordance with GAAP. Accordingly, the following table presents a reconciliation of adjusted operating cash flow and adjusted free cash flow to net cash provided by operating activities, which is the most directly comparable financial measure calculated and presented in accordance with GAAP: Three Months Ended December 31, Year Ended December 31, (in thousands) 2024 2023 2024 2023 Net cash provided by operating activities $ 871,578 $ 845,994 $ 3,411,968 $ 2,213,499 Changes in working capital: Accounts receivable 103,963 (94,123) 51,396 (36,336) Prepaid and other assets 1,663 (543) 8,491 27,267 Accounts payable and other liabilities (73,735) (58,365) (78,353) (83,160) Merger and integration expense & other — 97,260 25,659 125,331 Estimated tax distribution to noncontrolling interest owners (1) 582 — — — Adjusted operating cash flow 904,051 790,223 3,419,161 2,246,601 Less: total cash capital expenditures (504,459) (458,206) (2,060,667) (1,524,899) Adjusted free cash flow $ 399,592 $ 332,017 $ 1,358,494 $ 721,702 Adjusted diluted weighted average shares outstanding 847,094 744,958 829,058 637,607 (1) Reflects estimated future distributions for noncontrolling interest owners based upon current federal and state income tax expense recognized during the period and expected to be paid by the partnership. Such estimates are based upon the noncontrolling interest ownership percentage as of the three months ended December 31, 2024. Adjusted Net Income Adjusted net income is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. We define adjusted net income as net income attributable to Class A Common Stock plus net income attributable to noncontrolling interest adjusted for non-cash gains or losses on derivatives, merger and integration expense, other nonrecurring charges, impairment and abandonment expense, gain/loss from the sale of long-lived assets and the related income tax adjustments for these items. Adjusted net income is not a measure of net income as determined by GAAP. Our management believes adjusted net income is useful as it allows them to more effectively evaluate our operating performance and compare the results of our operations from period to period and against our peers by excluding certain non-cash items that can vary significantly. Adjusted net income should not be considered as an alternative to, or more meaningful than, net income as determined in accordance with GAAP or as an indicator of our operating performance or liquidity. Our presentation of adjusted net income should not be construed as an inference that our results will be unaffected by unusual or nonrecurring items. Our computations of adjusted net income may not be comparable to other similarly titled measures of other companies. Adjusted net income is not a financial measure that is determined in accordance with GAAP. Accordingly, the following table presents a reconciliation of adjusted net income to net income, which is the most directly comparable financial measure calculated and presented in accordance with GAAP: Three Months Ended December 31, Year Ended December 31, (in thousands, except per share data) 2024 2023 2024 2023 Net income attributable to Class A Common Stock $ 216,650 $ 255,354 $ 984,701 $ 476,306 Net income attributable to noncontrolling interest 38,829 157,265 265,808 403,397 Non-cash derivative (gain) loss 73,579 (180,179) (17,783) (14,606) Merger and integration expense & other — 97,260 25,659 125,331 Impairment and abandonment expense 2,128 5,947 9,912 6,681 (Gain) loss on sale of long-lived assets 66 (82) (375) (211) Adjusted net income excluding above items 331,252 335,565 1,267,922 996,898 Income tax (expense) benefit attributable to the above items (1) (25,785) (18,047) (63,725) (117,133) Adjusted Net Income $ 305,467 $ 317,518 $ 1,204,197 $ 879,765 Interest on Convertible Senior Notes, net of tax 1,294 1,361 5,182 5,433 Adjusted Net Income - Diluted $ 306,761 $ 318,879 $ 1,209,379 $ 885,198 Adjusted diluted weighted average shares outstanding (Non-GAAP) (2) 847,094 744,958 829,058 637,607 Adjusted net income per adjusted diluted share $ 0.36 $ 0.43 $ 1.46 $ 1.39 (1) Income tax (expense) benefit for adjustments made to adjusted net income is calculated using PR's federal and state-apportioned statutory tax rate of 22.5%. (2) Adjusted diluted weighted average shares outstanding is a Non-GAAP measure that has been computed and reconciled to the nearest GAAP metric in the preceding table above. The following table summarizes the approximate volumes and average contract prices of the hedge contracts the Company had in place as of December 31, 2024 and additional contracts entered into through February 21, 2025: Period Volume (Bbls) Volume (Bbls/d) Wtd. Avg. Crude Price ($/Bbl) (1) Crude oil swaps January 2025 - March 2025 4,050,000 45,000 $75.21 April 2025 - June 2025 4,095,000 45,000 73.87 July 2025 - September 2025 4,140,000 45,000 72.64 October 2025 - December 2025 4,140,000 45,000 71.60 January 2026 - March 2026 1,575,000 17,500 71.49 April 2026 - June 2026 1,592,500 17,500 70.61 July 2026 - September 2026 1,610,000 17,500 69.77 October 2026 - December 2026 1,610,000 17,500 69.08 Period Volume (Bbls) Volume (Bbls/d) Wtd. Avg. Differential ($/Bbl) (2) Crude oil basis differential swaps January 2025 - March 2025 3,932,000 43,689 $1.11 April 2025 - June 2025 4,095,000 45,000 1.10 July 2025 - September 2025 4,140,000 45,000 1.10 October 2025 - December 2025 4,140,000 45,000 1.10 January 2026 - March 2026 1,575,000 17,500 1.15 April 2026 - June 2026 1,592,500 17,500 1.15 July 2026 - September 2026 1,610,000 17,500 1.15 October 2026 - December 2026 1,610,000 17,500 1.15 Period Volume (Bbls) Volume (Bbls/d) Wtd. Avg. Differential ($/Bbl) (3) Crude oil roll differential swaps January 2025 - March 2025 3,932,000 43,689 $0.43 April 2025 - June 2025 4,095,000 45,000 0.44 July 2025 - September 2025 4,140,000 45,000 0.44 October 2025 - December 2025 4,140,000 45,000 0.44 January 2026 - March 2026 1,575,000 17,500 0.28 April 2026 - June 2026 1,592,500 17,500 0.28 July 2026 - September 2026 1,610,000 17,500 0.28 October 2026 - December 2026 1,610,000 17,500 0.28 (1) These crude oil swap transactions are settled based on the NYMEX WTI index price on each trading day within the specified monthly settlement period versus the contractual swap price for the volumes stipulated. (2) These crude oil basis swap transactions are settled based on the difference between the arithmetic average of ARGUS MIDLAND WTI and ARGUS WTI CUSHING indices, during each applicable monthly settlement period. (3) These crude oil roll swap transactions are settled based on the difference between the arithmetic average of NYMEX WTI calendar month prices and the physical crude oil delivery month price. Period Volume (MMBtu) Volume (MMBtu/d) Wtd. Avg. Gas Price ($/MMBtu) (1) Natural gas swaps January 2025 - March 2025 11,070,000 123,000 $3.44 April 2025 - June 2025 11,193,000 123,000 3.12 July 2025 - September 2025 11,316,000 123,000 3.43 October 2025 - December 2025 11,316,000 123,000 3.85 January 2026 - March 2026 8,190,000 91,000 4.08 April 2026 - June 2026 8,281,000 91,000 3.40 July 2026 - September 2026 8,372,000 91,000 3.65 October 2026 - December 2026 8,372,000 91,000 4.01 January 2027 - March 2027 12,600,000 140,000 4.24 April 2027 - June 2027 12,740,000 140,000 3.32 July 2027 - September 2027 12,880,000 140,000 3.58 October 2027 - December 2027 12,880,000 140,000 3.94 Period Volume (MMBtu) Volume (MMBtu/d) Wtd. Avg. Differential ($/MMBtu) (2) Natural gas basis differential swaps January 2025 - March 2025 11,070,000 123,000 $(0.83) April 2025 - June 2025 11,193,000 123,000 (1.35) July 2025 - September 2025 11,316,000 123,000 (1.23) October 2025 - December 2025 11,316,000 123,000 (1.25) January 2026 - March 2026 8,190,000 91,000 (1.09) April 2026 - June 2026 8,281,000 91,000 (2.27) July 2026 - September 2026 8,372,000 91,000 (1.29) October 2026 - December 2026 8,372,000 91,000 (0.98) January 2027 - March 2027 12,600,000 140,000 (0.46) April 2027 - June 2027 12,740,000 140,000 (1.11) July 2027 - September 2027 12,880,000 140,000 (0.62) October 2027 - December 2027 12,880,000 140,000 (0.87) (1) These natural gas swap contracts are settled based on the NYMEX Henry Hub price on each trading day within the specified monthly settlement period versus the contractual swap price for the volumes stipulated. (2) These natural gas basis swap contracts are settled based on the difference between the Inside FERC’s West Texas WAHA price and the NYMEX price of natural gas during each applicable monthly settlement period.

the item shown at left

other guidance in this release

Text is the filed exhibit, verbatim.