NEWS RELEASE Range Announces Third Quarter 2025 Results FORT WORTH, TEXAS, October 28, 2025…RANGE RESOURCES CORPORATION (NYSE: RRC) today announced its third quarter 2025 financial results. Third Quarter 2025 Highlights – • Cash flow from operating activities of $248 million • Cash flow from operations, before working capital changes, of $279 million • Repurchased $56 million of shares and paid $21 million in dividends • Capital spending was $190 million, approximately 29% of the annual 2025 budget • Realized price, including hedges, was $3.29 per mcfe – a $0.22 premium versus NYMEX natural gas • Pre-hedge NGL realizations of $22.09 per barrel – a premium of $0.33 over Mont Belvieu equivalent • Natural gas differential, including basis hedging, of ($0.49) per mcf to NYMEX • Production averaged 2.23 Bcfe per day, approximately 69% natural gas Commenting on the results, Dennis Degner, the Company’s CEO said, “Range’s third quarter results continue to showcase our ability to generate significant free cash flow through cycles, which supported $77 million in share repurchases and dividends, while maintaining net debt at $1.2 billion and continuing to build operational momentum. Our counter-cyclical investments in drilled inventory over the last two years support the very efficient growth we have planned through 2027, while keeping capital relatively flat. We believe Range is exceedingly well-positioned to benefit from growing local and global demand for natural gas given our consistent well results, high-return, long-life asset base and low full-cycle cost structure. Together, these advantages enable Range to help meet this demand while continuing to return meaningful capital to shareholders.” Financial Discussion Except for generally accepted accounting principles (“GAAP”) reported amounts, specific expense categories exclude non-cash impairments, unrealized mark-to-market adjustment on derivatives, non-cash stock compensation and other items shown separately on the attached tables. “Unit costs” as used in this release are composed of direct operating, transportation, gathering, processing and compression, taxes other than income, general and administrative, interest and depletion, depreciation and amortization costs divided by production. See “Non-GAAP Financial Measures” for a definition of non-GAAP financial measures and the accompanying tables that reconcile each non-GAAP measure to its most directly comparable GAAP financial measure. Third Quarter 2025 Results GAAP revenues and other income for third quarter 2025 totaled $749 million, GAAP net cash provided from operating activities (including changes in working capital) was $248 million, and GAAP net income was $144 million ($0.60 per diluted share). Third quarter earnings results include a $93 million mark-to-market derivative gain due to decreases in commodity prices. Cash flow from operations before changes in working capital, a non-GAAP measure, was $279 million. Adjusted net income comparable to analysts’ estimates, a non-GAAP measure, was $135 million ($0.57 per diluted share) in third quarter 2025. The following table details Range’s third quarter 2025 unit costs per mcfe (a) : Expenses 3Q 2025 (per mcfe) 3Q 2024 (per mcfe) Increase (Decrease) Direct operating (a) $ 0.11 $ 0.12 (8%) Transportation, gathering, processing and compression (a) 1.47 1.51 (3%) Taxes other than income 0.04 0.03 33% General and administrative (a) 0.17 0.16 6% Interest expense (a) 0.11 0.14 (21%) Total cash unit costs (b) 1.91 1.96 (3%) Depletion, depreciation and amortization (DD&A) 0.46 0.45 2% Total unit costs plus DD&A (b) $ 2.37 $ 2.41 (2%) (a) Excludes stock-based compensation, one-time settlements, and amortization of deferred financing costs. (b) Totals may not be exact due to rounding. The following table details Range’s average production and realized pricing for third quarter 2025 (a) : 3Q25 Production & Realized Pricing Natural Gas (mcf) Oil (bbl) NGLs (bbl) Natural Gas Equivalent (mcfe) Net production per day 1,534,065 5,208 110,420 2,227,831 Average NYMEX price $ 3.07 $64.98 $ 21.76 Differential, including basis hedging (0.49) (10.73) 0.33 Realized prices before NYMEX hedges 2.58 54.25 22.09 3.00 Settled NYMEX hedges 0.38 3.37 0.39 0.29 Average realized prices after hedges $ 2.96 $ 57.61 $ 22.48 $ 3.29 (a) Totals may not be exact due to rounding. Third quarter 2025 natural gas, NGLs and oil price realizations (including the impact of cash-settled hedges and derivative settlements) averaged $3.29 per mcfe. • The average natural gas price, including the impact of basis hedging, was $2.58 per mcf, or a ($0.49) per mcf differential to NYMEX. Range is improving its expected 2025 natural gas differential to average ($0.40) to ($0.43) relative to NYMEX. • Range’s pre-hedge NGL price during the quarter was $22.09 per barrel, approximately $0.33 above the Mont Belvieu weighted equivalent. Range now expects its 2025 NGL differential to average +$0.50 to +$0.75 relative to a Mont Belvieu equivalent barrel. • Oil and condensate price realizations, before realized hedges, averaged $54.25 per barrel, or $10.73 below WTI (West Texas Intermediate). Range continues to expect condensate differentials to average ($10.00) to ($15.00) relative to NYMEX. Repurchase Activity and Financial Position During the third quarter, Range repurchased 1,580,711 shares at an average price of approximately $35.59 per share. As of September 30, 2025, the Company had approximately $839 million of availability under the share repurchase program. As of September 30, 2025, Range had net debt outstanding of approximately $1.23 billion, consisting of $1.1 billion of senior notes, $129 million on the credit facility, and $0.2 million in cash. In October, Range entered an amended and restated revolving bank credit facility, which will mature in 2030. This amended facility maintained a maximum facility of $4.0 billion and an initial borrowing base of $3.0 billion, and increased bank commitments from $1.5 billion to $2.0 billion. Capital Expenditures and Operational Activity Third quarter 2025 drilling and completion expenditures were $165 million. In addition, during the quarter, approximately $16 million was invested in acreage, and $9 million was invested in infrastructure, pneumatic upgrades, and other investments. Total capital spending through third quarter was $491 million, representing approximately 74% of Range’s capital budget for 2025. During the quarter, Range drilled ~262,000 lateral feet across 16 wells, while turning to sales ~228,000 lateral feet across 15 wells. Range remains on track to exit 2025 with greater than 400,000 lateral feet of growth inventory to support announced growth plans. The table below summarizes expected 2025 activity plans regarding the number of wells to sales in each area. YTD Wells TIL 3Q 2025 Remaining 2025 2025 Planned TIL SW PA Super-Rich 8 6 14 SW PA Wet 20 4 24 SW PA Dry 5 - 5 NE PA Dry 4 - 4 Total Wells 37 10 47 Guidance – 2025 Updated Capital & Production Guidance Range’s 2025 all-in capital budget is $650 million - $680 million. Annual production is now expected to be approximately 2.23 Bcfe per day in 2025, updated from prior guidance of ~2.225 Bcfe per day. Liquids are expected to be over 30% of production. Updated Full Year 2025 Expense Guidance Updated Guidance Prior Guidance Direct operating expense: $0.12 - $0.13 per mcfe $0.12 - $0.13 per mcfe Transportation, gathering, processing and compression expense: $1.50 - $1.52 per mcfe $1.50 - $1.55 per mcfe Taxes other than income: $0.03 - $0.04 per mcfe $0.03 - $0.04 per mcfe Exploration expense: $24 - $28 million $24 - $28 million G&A expense: $0.17 - $0.18 per mcfe $0.17 - $0.18 per mcfe Net Interest expense: $0.12 - $0.13 per mcfe $0.12 - $0.13 per mcfe DD&A expense: $0.45 - $0.46 per mcfe $0.45 - $0.46 per mcfe Net brokered gas marketing expense: $8 - $12 million $8 - $12 million Updated Full Year 2025 Price Guidance Based on recent market indications, Range expects to average the following price differentials for its production in 2025. Updated Guidance Prior Guidance FY 2025 Natural Gas: (a) NYMEX minus $0.40 to $0.43 NYMEX minus $0.40 to $0.48 FY 2025 Natural Gas Liquids: (b) MB plus $0.50 to $0.75 per barrel MB plus $0.40 to $1.25 per barrel FY 2025 Oil/Condensate: WTI minus $10.00 to $15.00 WTI minus $10.00 to $15.00 (a) Including basis hedging. (b) Mont Belvieu-equivalent pricing based on weighting of 53% ethane, 27% propane, 8% normal butane, 4% iso-butane and 8% natural gasoline. Hedging Status Range hedges portions of its expected future production volumes to increase the predictability of cash flow and maintain a strong, flexible financial position. Please see the detailed hedging schedule posted on the Range website under Investor Relations - Financial Information. Range has also hedged basis across the Company’s numerous natural gas sales points to limit volatility between benchmark and regional prices. The combined fair value of basis hedges as of September 30, 2025, was a net loss of $12.9 million. Conference Call Information A conference call to review the financial results is scheduled on Wednesday, October 29 at 8:00 AM Central Time (9:00 AM Eastern Time). Please click here to pre-register for the conference call and obtain a dial in number with passcode. A simultaneous webcast of the call may be accessed at www.rangeresources.com . The webcast will be archived for replay on the Company's website until November 29 th . Non-GAAP Financial Measures To supplement the presentation of its financial results prepared in accordance with generally accepted accounting principles (GAAP), the Company’s earnings press release contains certain financial measures that are not presented in accordance with GAAP. Management believes certain non-GAAP measures may provide financial statement users with meaningful supplemental information for comparisons within the industry. These non-GAAP financial measures may include, but are not limited to Net Income, excluding certain items, Cash flow from operations before changes in working capital, realized prices, Net debt and Cash margin. Adjusted net income comparable to analysts’ estimates as set forth in this release represents income or loss from operations before income taxes adjusted for certain non-cash items (detailed in the accompanying table) less income taxes. We believe adjusted net income comparable to analysts’ estimates is calculated on the same basis as analysts’ estimates and that many investors use this published research in making investment decisions and evaluating operational trends of the Company and its performance relative to other oil and gas producing companies. Diluted earnings per share (adjusted) as set forth in this release represents adjusted net income comparable to analysts’ estimates on a diluted per share basis. A table is included which reconciles income or loss from operations to adjusted net income comparable to analysts’ estimates and diluted earnings per share (adjusted). On its website, the Company provides additional comparative information on prior periods. Cash flow from operations before changes in working capital represents net cash provided by operations before changes in working capital and exploration expense adjusted for certain non-cash compensation items. Cash flow from operations before changes in working capital (sometimes referred to as “adjusted cash flow”) is widely accepted by the investment community as a financial indicator of an oil and gas company’s ability to generate cash to internally fund exploration and development activities and to service debt. Cash flow from operations before changes in working capital is also useful because it is widely used by professional research analysts in valuing, comparing, rating and providing investment recommendations of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Cash flow from operations before changes in working capital is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operations, investing, or financing activities as an indicator of cash flows, or as a measure of liquidity. A table is included which reconciles net cash provided by operations to cash flow from operations before changes in working capital as used in this release. On its website, the Company provides additional comparative information on prior periods for cash flow, cash margins and non-GAAP earnings as used in this release. The cash prices realized for oil and natural gas production, including the amounts realized on cash-settled derivatives and net of transportation, gathering, processing and compression expense, is a critical component in the Company’s performance tracked by investors and professional research analysts in valuing, comparing, rating and providing investment recommendations and forecasts of companies in the oil and gas exploration and production industry. In turn, many investors use this published research in making investment decisions. Due to the GAAP disclosures of various derivative transactions and third-party transportation, gathering, processing and compression expense, such information is now reported in various lines of the income statement. The Company believes that it is important to furnish a table reflecting the details of the various components of each income statement line to better inform the reader of the details of each amount and provide a summary of the realized cash-settled amounts and third-party transportation, gathering, processing and compression expense, which were historically reported as natural gas, NGLs and oil sales. This information is intended to bridge the gap between various readers’ understanding and fully disclose the information needed. Net debt is calculated as total debt less cash and cash equivalents. The Company believes this measure is helpful to investors and industry analysts who utilize Net debt for comparative purposes across the industry. The Company discloses in this release the detailed components of many of the single line items shown in the GAAP financial statements included in the Company’s Annual or Quarterly Reports on Form 10-K or 10-Q. The Company believes that it is important to furnish this detail of the various components comprising each line of the Statements of Operations to better inform the reader of the details of each amount, the changes between periods and the effect on its financial results. We believe that the presentation of PV 10 value of our proved reserves is a relevant and useful metric for our investors as supplemental disclosure to the standardized measure, or after-tax amount, because it presents the discounted future net cash flows attributable to our proved reserves before taking into account future corporate income taxes and our current tax structure. While the standardized measure is dependent on the unique tax situation of each company, PV 10 is based on prices and discount factors that are consistent for all companies. Because of this, PV 10 can be used within the industry and by credit and security analysts to evaluate estimated net cash flows from proved reserves on a more comparable basis. RANGE RESOURCES CORPORATION (NYSE: RRC) is a leading U.S. independent natural gas and NGL producer with operations focused in the Appalachian Basin. The Company is headquartered in Fort Worth, Texas. More information about Range can be found at www.rangeresources.com . Included within this release are certain “forward-looking statements” within the meaning of the federal securities laws, including the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, that are not limited to historical facts, but reflect Range’s current beliefs, expectations or intentions regarding future events. Words such as “may,” “will,” “could,” “should,” “expect,” “plan,” “project,” “intend,” “anticipate,” “believe,” “outlook”, “estimate,” “predict,” “potential,” “pursue,” “target,” “continue,” and similar expressions are intended to identify such forward-looking statements. All statements, except for statements of historical fact, made within regarding activities, events or developments the Company expects, believes or anticipates will or may occur in the future, such as those regarding future well costs, expected asset sales, well productivity, future liquidity and financial resilience, anticipated exports and related financial impact, NGL market supply and demand, future commodity fundamentals and pricing, future capital efficiencies, future shareholder value, emerging plays, capital spending, anticipated drilling and completion activity, acreage prospectivity, expected pipeline utilization and future guidance information, are 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. These statements are based on assumptions and estimates that management believes are reasonable based on currently available information; however, management's assumptions and Range's future performance are subject to a wide range of business risks and uncertainties and there is no assurance that these goals and projections can or will be met. Any number of factors could cause actual results to differ materially from those in the forward-looking statements. Further information on risks and uncertainties is available in Range's filings with the Securities and Exchange Commission (SEC), including its most recent Annual Report on Form 10-K. Unless required by law, Range undertakes no obligation to publicly update or revise any forward-looking statements to reflect circumstances or events after the date they are made. The SEC permits oil and gas companies, in filings made with the SEC, to disclose proved reserves, which are 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 as well as the option to disclose probable and possible reserves. Range has elected not to disclose its probable and possible reserves in its filings with the SEC. Range uses certain broader terms such as "resource potential,” “unrisked resource potential,” "unproved resource potential" or "upside" or other descriptions of volumes of resources potentially recoverable through additional drilling or recovery techniques that may include probable and possible reserves as defined by the SEC's guidelines. Range has not attempted to distinguish probable and possible reserves from these broader classifications. The SEC’s rules prohibit us from including in filings with the SEC these broader classifications of reserves. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of actually being realized. Unproved resource potential refers to Range's internal estimates of hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques and have not been reviewed by independent engineers. Unproved resource potential does not constitute reserves within the meaning of the Society of Petroleum Engineer's Petroleum Resource Management System and does not include proved reserves. Area wide unproven resource potential has not been fully risked by Range's management. “EUR”, or estimated ultimate recovery, refers to our management’s estimates of hydrocarbon quantities that may be recovered from a well completed as a producer in the area. These quantities may not necessarily constitute or represent reserves within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or the SEC’s oil and natural gas disclosure rules. Actual quantities that may be recovered from Range's interests could differ substantially. Factors affecting ultimate recovery include the scope of Range's drilling program, which will be directly affected by the availability of capital, drilling and production costs, commodity prices, availability of drilling services and equipment, drilling results, lease expirations, transportation constraints, regulatory approvals, field spacing rules, recoveries of gas in place, length of horizontal laterals, actual drilling results, including geological and mechanical factors affecting recovery rates and other factors. Estimates of resource potential may change significantly as development of our resource plays provides additional data. In addition, our 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 or drilling cost changes. Investors are urged to consider closely the disclosure in our most recent Annual Report on Form 10-K, available from our website at www.rangeresources.com or by written request to 100 Throckmorton Street, Suite 1200, Fort Worth, Texas 76102. You can also obtain this Form 10-K on the SEC’s website at www.sec.gov or by calling the SEC at 1-800-SEC-0330. SOURCE: Range Resources Corporation Range Investor Contacts: Laith Sando 817-869-4267 Matt Schmid 817-869-1538 Range Media Contact: Mark Windle 724-873-3223 RANGE RESOURCES CORPORATION STATEMENTS OF OPERATIONS Based on GAAP reported earnings with additional details of items included in each line in Form 10-Q (Unaudited, In thousands, except per share data) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 % 2025 2024 % Revenues and other income: Natural gas, NGLs and oil sales (a) $ 611,491 $ 533,277 $ 2,070,049 $ 1,578,728 Derivative fair value income 92,946 47,124 88,736 110,530 Brokered natural gas and marketing 43,807 31,289 131,224 91,513 ARO settlement (loss) gain (b) - - 1 (26 ) Interest income (b) 52 3,188 4,867 9,507 Loss (gain) on sale of assets (b) (6 ) 69 158 222 Other (b) 238 155 322 193 Total revenues and other income 748,528 615,102 22 % 2,295,357 1,790,667 28 % Costs and expenses: Direct operating 23,305 24,799 70,757 68,744 Direct operating - stock-based compensation (c) 525 486 1,566 1,454 Transportation, gathering, processing and compression 301,110 306,154 911,933 878,524 Taxes other than income 8,265 5,117 23,087 15,459 Brokered natural gas and marketing 48,256 32,017 139,800 96,425 Brokered natural gas and marketing - stock-based compensation (c) 626 571 2,268 1,862 Exploration 7,820 6,988 21,426 17,506 Exploration - stock-based compensation (c) 285 346 998 1,005 Abandonment and impairment of unproved properties 4,899 4,723 16,254 8,618 General and administrative 35,253 32,674 99,563 97,818 General and administrative - stock-based compensation (c) 9,448 8,639 28,885 27,099 General and administrative - lawsuit settlements 11 213 101 691 Exit costs 8,085 7,649 25,484 28,058 Deferred compensation plan (d) (765 ) (1,930 ) 2,026 5,715 Interest expense 23,200 27,958 76,615 85,430 Interest expense - amortization of deferred financing costs (e) 1,068 1,343 3,610 4,060 Gain on early extinguishment of debt - (11 ) (3 ) (254 ) Depletion, depreciation and amortization 93,793 91,137 275,866 265,872 Total costs and expenses 565,184 548,873 3 % 1,700,236 1,604,086 6 % Income before income taxes 183,344 66,229 177 % 595,121 186,581 219 % Income tax expense (benefit) Current (1,022 ) 1,282 5,623 5,263 Deferred 40,059 14,291 110,561 9,820 39,037 15,573 116,184 15,083 Net income $ 144,307 $ 50,656 185 % $ 478,937 $ 171,498 179 % Net income Per Common Share Basic $ 0.61 $ 0.21 $ 2.00 $ 0.71 Diluted $ 0.60 $ 0.21 $ 1.99 $ 0.70 Weighted average common shares outstanding, as reported Basic 237,378 240,865 -1 % 238,523 240,832 -1 % Diluted 239,026 242,623 -1 % 240,255 242,802 -1 % (a) See separate natural gas, NGLs and oil sales information table. (b) Included in Other income in the 10-Q. (c) Costs associated with stock compensation and restricted stock amortization, which have been reflected in the categories associated with the direct personnel costs, which are combined with the cash costs in the 10-Q. (d) Reflects the change in market value of the vested Company stock held in the deferred compensation plan. (e) Included in interest expense in the 10-Q. RANGE RESOURCES CORPORATION BALANCE SHEET (In thousands) September 30, December 31, 2025 2024 (Unaudited) (Audited) Assets Current assets $ 274,431 $ 636,982 Derivative assets 62,152 87,098 Natural gas and oil properties, net (successful efforts method) 6,627,222 6,421,700 Other property and equipment, net 3,464 2,465 Operating lease right-of-use assets 154,842 119,838 Other 75,652 79,592 $ 7,197,763 $ 7,347,675 Liabilities and Stockholders' Equity Current liabilities $ 591,453 $ 1,263,247 Asset retirement obligations 1,189 1,189 Derivative liabilities 2,464 9,634 Bank debt 125,650 - Senior notes, excluding current maturities 1,091,117 1,089,614 Deferred tax liabilities 650,428 541,378 Derivative liabilities 2,049 10,488 Deferred compensation liabilities 67,293 65,233 Operating lease liabilities 95,937 35,737 Asset retirement obligations and other liabilities 145,640 137,181 Divestiture contract obligation 221,035 257,317 2,994,255 3,411,018 Common stock and retained deficit 4,894,936 4,449,987 Other comprehensive income 568 611 Common stock held in treasury (691,996 ) (513,941 ) Total stockholders' equity 4,203,508 3,936,657 $ 7,197,763 $ 7,347,675 RECONCILIATION OF TOTAL DEBT AS REPORTED TO NET DEBT, a non-GAAP measure (Unaudited, in thousands) September 30, December 31, 2025 2024 % Total debt, net of deferred financing costs, as reported $ 1,216,767 $ 1,697,883 -28 % Unamortized debt issuance costs, as reported 12,233 10,819 Less cash and cash equivalents, as reported (175 ) (304,490 ) Net debt, a non-GAAP measure $ 1,228,825 $ 1,404,212 -12 % RANGE RESOURCES CORPORATION CASH FLOWS FROM OPERATING ACTIVITIES (Unaudited, in thousands) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 2025 2024 Net income $ 144,307 $ 50,656 $ 478,937 $ 171,498 Adjustments to reconcile net cash provided from continuing operations: Deferred income tax expense 40,059 14,291 110,561 9,820 Depletion, depreciation and amortization 93,793 91,137 275,866 265,872 Abandonment and impairment of unproved properties 4,899 4,723 16,254 8,618 Derivative fair value income (92,946 ) (47,124 ) (88,736 ) (110,530 ) Cash settlements on derivative financial instruments 62,033 112,265 98,072 362,695 Divestiture contract obligation, including accretion 8,085 7,604 25,484 27,933 Amortization of deferred financing costs and other 852 927 2,996 3,352 Deferred and stock-based compensation 10,248 8,260 36,378 37,597 Loss (gain) on sale of assets 6 (69 ) (158 ) (222 ) Loss (gain) on early extinguishment of debt - (11 ) (3 ) (254 ) Changes in working capital: Accounts receivable (5,001 ) 24,617 63,063 101,530 Other current assets 3,426 20,596 (5,084 ) (1,809 ) Accounts payable (1,142 ) (21,334 ) 8,016 (27,052 ) Accrued liabilities and other (21,074 ) (20,619 ) (107,828 ) (122,424 ) Net changes in working capital (23,791 ) 3,260 (41,833 ) (49,755 ) Net cash provided from operating activities $ 247,545 $ 245,919 $ 913,818 $ 726,624 RECONCILIATION OF NET CASH PROVIDED FROM OPERATING ACTIVITIES, AS REPORTED, TO CASH FLOW FROM OPERATIONS BEFORE CHANGES IN WORKING CAPITAL, a non-GAAP measure (Unaudited, in thousands) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 2025 2024 Net cash provided from operating activities, as reported $ 247,545 $ 245,919 $ 913,818 $ 726,624 Net changes in working capital 23,791 (3,260 ) 41,833 49,755 Exploration expense 7,820 6,988 21,426 17,506 Lawsuit settlements 11 213 101 691 Non-cash compensation adjustment and other 87 313 (22 ) 397 Cash flow from operations before changes in working capital - non-GAAP measure $ 279,254 $ 250,173 $ 977,156 $ 794,973 ADJUSTED WEIGHTED AVERAGE SHARES OUTSTANDING (Unaudited, in thousands) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 2025 2024 Basic: Weighted average shares outstanding 237,643 241,676 239,063 242,133 Stock held by deferred compensation plan (265 ) (811 ) (540 ) (1,301 ) Adjusted basic 237,378 240,865 238,523 240,832 Dilutive: Weighted average shares outstanding 237,643 241,676 239,063 242,133 Dilutive stock options under treasury method 1,383 947 1,192 669 Adjusted dilutive 239,026 242,623 240,255 242,802 RANGE RESOURCES CORPORATION RECONCILIATION OF NATURAL GAS, NGLs AND OIL SALES AND DERIVATIVE FAIR VALUE INCOME (LOSS) TO CALCULATED CASH REALIZED NATURAL GAS, NGLs AND OIL PRICES WITH AND WITHOUT THIRD-PARTY TRANSPORTATION, GATHERING, PROCESSING AND COMPRESSION COSTS, a non-GAAP measure (Unaudited, In thousands, except per unit data) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 % 2025 2024 % Natural gas, NGLs and Oil Sales components: Natural gas sales $ 361,124 $ 234,139 $ 1,249,456 $ 715,266 NGLs sales 224,376 266,186 738,064 750,547 Oil sales 25,991 32,952 82,529 112,915 Total Natural Gas, NGLs and Oil Sales, as reported $ 611,491 $ 533,277 15 % $ 2,070,049 $ 1,578,728 31 % Derivative Fair Value Income, as reported $ 92,946 $ 47,124 $ 88,736 $ 110,530 Cash settlements on derivative financial instruments - (gain) loss: Natural gas (56,420 ) (107,923 ) (90,263 ) (355,030 ) NGLs (4,000 ) (1,409 ) (5,096 ) (3,310 ) Oil (1,613 ) (2,933 ) (2,713 ) (4,355 ) Total change in fair value related to commodity derivatives prior to settlement, a non-GAAP measure $ 30,913 $ (65,141 ) $ (9,336 ) $ (252,165 ) Transportation, gathering, processing and compression components: Natural Gas $ 157,193 $ 153,063 $ 469,416 $ 456,215 NGLs 142,815 152,624 439,862 420,975 Oil 1,102 467 2,655 1,334 Total transportation, gathering, processing and compression, as reported $ 301,110 $ 306,154 $ 911,933 $ 878,524 Natural gas, NGL and Oil sales, including cash-settled derivatives: (c) Natural gas sales $ 417,544 $ 342,062 $ 1,339,719 $ 1,070,296 NGLs sales 228,376 267,595 743,160 753,857 Oil Sales 27,604 35,885 85,242 117,270 Total $ 673,524 $ 645,542 4 % $ 2,168,121 $ 1,941,423 12 % Production of natural gas, NGLs and oil during the periods (a): Natural Gas (mcf) 141,133,949 138,193,783 2 % 413,394,538 406,943,086 2 % NGLs (bbls) 10,158,612 10,254,759 -1 % 30,107,652 29,392,292 2 % Oil (bbls) 479,142 514,659 -7 % 1,483,512 1,717,958 -14 % Gas equivalent (mcfe) (b) 204,960,473 202,810,291 1 % 602,941,522 593,604,586 2 % Production of natural gas, NGLs and oil - average per day (a): Natural Gas (mcf) 1,534,065 1,502,106 2 % 1,514,266 1,485,194 2 % NGLs (bbls) 110,420 111,465 -1 % 110,284 107,271 3 % Oil (bbls) 5,208 5,594 -7 % 5,434 6,270 -13 % Gas equivalent (mcfe) (b) 2,227,831 2,204,460 1 % 2,208,577 2,166,440 2 % Average prices, excluding derivative settlements and before third-party transportation costs: Natural Gas (per mcf) $ 2.56 $ 1.69 51 % $ 3.02 $ 1.76 72 % NGLs (per bbl) $ 22.09 $ 25.96 -15 % $ 24.51 $ 25.54 -4 % Oil (per bbl) $ 54.25 $ 64.03 -15 % $ 55.63 $ 65.73 -15 % Gas equivalent (per mcfe) (b) $ 2.98 $ 2.63 13 % $ 3.43 $ 2.66 29 % Average prices, including derivative settlements before third-party transportation costs: (c) Natural Gas (per mcf) $ 2.96 $ 2.48 19 % $ 3.24 $ 2.63 23 % NGLs (per bbl) $ 22.48 $ 26.09 -14 % $ 24.68 $ 25.65 -4 % Oil (per bbl) $ 57.61 $ 69.73 -17 % $ 57.46 $ 68.26 -16 % Gas equivalent (per mcfe) (b) $ 3.29 $ 3.18 3 % $ 3.59 $ 3.27 10 % Average prices, including derivative settlements and after third-party transportation costs: (d) Natural Gas (per mcf) $ 1.84 $ 1.37 34 % $ 2.11 $ 1.51 40 % NGLs (per bbl) $ 8.42 $ 11.21 -25 % $ 10.07 $ 11.33 -11 % Oil (per bbl) $ 55.31 $ 68.82 -20 % $ 55.67 $ 67.49 -18 % Gas equivalent (per mcfe) (b) $ 1.82 $ 1.67 9 % $ 2.08 $ 1.79 16 % Transportation, gathering and compression expense per mcfe $ 1.47 $ 1.51 -3 % $ 1.51 $ 1.48 2 % (a) Represents volumes sold regardless of when produced. (b) Oil and NGLs are converted at the rate of one barrel equals six mcfe based upon the approximate relative energy content of oil to natural gas, which is not necessarily indicative of the relationship of oil and natural gas prices. (c) Excluding third-party transportation, gathering, processing and compression costs. (d) Net of transportation, gathering, processing and compression costs. RANGE RESOURCES CORPORATION RECONCILIATION OF INCOME BEFORE INCOME TAXES AS REPORTED TO INCOME BEFORE INCOME TAXES EXCLUDING CERTAIN ITEMS, a non-GAAP measure (Unaudited, In thousands, except per share data) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 % 2025 2024 % Income from operations before income taxes, as reported $ 183,344 $ 66,229 177 % $ 595,121 $ 186,581 219 % Adjustment for certain special items: Loss (gain) on the sale of assets 6 (69 ) (158 ) (222 ) ARO settlement loss (gain) - - (1 ) 26 Change in fair value related to derivatives prior to settlement (30,913 ) 65,141 9,336 252,165 Abandonment and impairment of unproved properties 4,899 4,723 16,254 8,618 Loss (gain) on early extinguishment of debt - (11 ) (3 ) (254 ) Lawsuit settlements 11 213 101 691 Exit costs 8,085 7,649 25,484 28,058 Brokered natural gas and marketing - stock-based compensation 626 571 2,268 1,862 Direct operating - stock-based compensation 525 486 1,566 1,454 Exploration expenses - stock-based compensation 285 346 998 1,005 General & administrative - stock-based compensation 9,448 8,639 28,885 27,099 Deferred compensation plan - non-cash adjustment (765 ) (1,930 ) 2,026 5,715 Income before income taxes, as adjusted 175,551 151,987 16 % 681,877 512,798 33 % Income tax expense (benefit), as adjusted Current (1,022 ) 1,282 5,623 5,263 Deferred (a) 41,399 33,675 151,209 112,681 Net income, excluding certain items, a non-GAAP measure $ 135,174 $ 117,030 16 % $ 525,045 $ 394,854 33 % Non-GAAP income per common share Basic $ 0.57 $ 0.49 16 % $ 2.20 $ 1.64 34 % Diluted $ 0.57 $ 0.48 19 % $ 2.19 $ 1.63 34 % Non-GAAP diluted shares outstanding, if dilutive 239,026 242,623 240,255 242,802 (a) Taxes are estimated to be approximately 23% for 2024 and 2025. RANGE RESOURCES CORPORATION RECONCILIATION OF NET INCOME, EXCLUDING CERTAIN ITEMS AND ADJUSTED EARNINGS PER SHARE, non-GAAP measures (In thousands, except per share data) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 2025 2024 Net income, as reported $ 144,307 $ 50,656 $ 478,937 $ 171,498 Adjustments for certain special items: Loss (gain) on the sale of assets 6 (69 ) (158 ) (222 ) ARO settlement loss (gain) - - (1 ) 26 Gain on early extinguishment of debt - (11 ) (3 ) (254 ) Change in fair value related to derivatives prior to settlement (30,913 ) 65,141 9,336 252,165 Abandonment and impairment of unproved properties 4,899 4,723 16,254 8,618 Lawsuit settlements 11 213 101 691 Exit costs 8,085 7,649 25,484 28,058 Stock-based compensation 10,884 10,042 33,717 31,420 Deferred compensation plan (765 ) (1,930 ) 2,026 5,715 Tax impact (1,340 ) (19,384 ) (40,648 ) (102,861 ) Net income, excluding certain items, a non-GAAP measure $ 135,174 $ 117,030 $ 525,045 $ 394,854 Net income per diluted share, as reported $ 0.60 $ 0.21 $ 1.99 $ 0.70 Adjustments for certain special items per diluted share: Loss (gain) on the sale of assets - - - - ARO settlement loss (gain) - - - - Gain on early extinguishment of debt - - - - Change in fair value related to derivatives prior to settlement (0.13 ) 0.27 0.04 1.04 Abandonment and impairment of unproved properties 0.02 0.02 0.07 0.04 Lawsuit settlements - - - - Exit costs 0.03 0.03 0.11 0.12 Stock-based compensation 0.05 0.04 0.14 0.13 Deferred compensation plan - (0.01 ) 0.01 0.02 Adjustment for rounding differences 0.01 - - - Tax impact (0.01 ) (0.08 ) (0.17 ) (0.42 ) Dilutive share impact (rabbi trust and other) - - - - Net income per diluted share, excluding certain items, a non-GAAP measure $ 0.57 $ 0.48 $ 2.19 $ 1.63 Adjusted earnings per share, a non-GAAP measure: Basic $ 0.57 $ 0.49 $ 2.20 $ 1.64 Diluted $ 0.57 $ 0.48 $ 2.19 $ 1.63 RANGE RESOURCES CORPORATION RECONCILIATION OF CASH MARGIN PER MCFE, a non- GAAP measure (Unaudited, In thousands, except per unit data) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 2025 2024 Revenues Natural gas, NGLs and oil sales, as reported $ 611,491 $ 533,277 $ 2,070,049 $ 1,578,728 Derivative fair value income, as reported 92,946 47,124 88,736 110,530 Less non-cash fair value (gain) loss (30,913 ) 65,141 9,336 252,165 Brokered natural gas and marketing, as reported 43,807 31,289 131,224 91,513 Other income, as reported 284 3,412 5,348 9,896 Less loss (gain) on sale of assets 6 (69 ) (158 ) (222 ) Less ARO settlement - - (1 ) 26 Cash revenues 717,621 680,174 2,304,534 2,042,636 Expenses Direct operating, as reported 23,830 25,285 72,323 70,198 Less direct operating stock-based compensation (525 ) (486 ) (1,566 ) (1,454 ) Transportation, gathering and compression, as reported 301,110 306,154 911,933 878,524 Taxes other than income, as reported 8,265 5,117 23,087 15,459 Brokered natural gas and marketing, as reported 48,882 32,588 142,068 98,287 Less brokered natural gas and marketing stock-based compensation (626 ) (571 ) (2,268 ) (1,862 ) General and administrative, as reported 44,712 41,526 128,549 125,608 Less G&A stock-based compensation (9,448 ) (8,639 ) (28,885 ) (27,099 ) Less lawsuit settlements (11 ) (213 ) (101 ) (691 ) Interest expense, as reported 24,268 29,301 80,225 89,490 Less amortization of deferred financing costs (1,068 ) (1,343 ) (3,610 ) (4,060 ) Cash expenses 439,389 428,719 1,321,755 1,242,400 Cash margin, a non-GAAP measure $ 278,232 $ 251,455 $ 982,779 $ 800,236 Mmcfe produced during period 204,961 202,810 602,942 593,605 Cash margin per mcfe $ 1.36 $ 1.24 $ 1.63 $ 1.35 RECONCILIATION OF INCOME BEFORE INCOME TAXES TO CASH MARGIN, a non-GAAP measure (Unaudited, in thousands, except per unit data) Three Months Ended September 30, Nine Months Ended September 30, 2025 2024 2025 2024 Income before income taxes, as reported $ 183,344 $ 66,229 $ 595,121 $ 186,581 Adjustments to reconcile income before income taxes to cash margin: ARO settlements - - (1 ) 26 Derivative fair value income (92,946 ) (47,124 ) (88,736 ) (110,530 ) Net cash receipts on derivative settlements 62,033 112,265 98,072 362,695 Exploration expense 7,820 6,988 21,426 17,506 Lawsuit settlements 11 213 101 691 Exit costs 8,085 7,649 25,484 28,058 Deferred compensation plan (765 ) (1,930 ) 2,026 5,715 Stock-based compensation (direct operating, brokered natural gas and 10,884 10,042 33,717 31,420 marketing and general and administrative) Bad debt expense - - - - Interest - amortization of deferred financing costs 1,068 1,343 3,610 4,060 Depletion, depreciation and amortization 93,793 91,137 275,866 265,872 Loss (gain) on sale of assets 6 (69 ) (158 ) (222 ) Gain on early extinguishment of debt - (11 ) (3 ) (254 ) Abandonment and impairment of unproved properties 4,899 4,723 16,254 8,618 Cash margin, a non-GAAP measure $ 278,232 $ 251,455 $ 982,779 $ 800,236

the item shown at left

other guidance in this release

Text is the filed exhibit, verbatim.