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EOG Resources Reports Second Quarter 2025 Results and Updates 2025 Guidance
HOUSTON, Aug. 7, 2025 /PRNewswire/ -- EOG Resources, Inc. (EOG) today reported second quarter 2025 results and updated its 2025 guidance. The attached supplemental financial tables and schedules for the reconciliation of non-GAAP measures to GAAP measures and related definitions and discussion, along with a related presentation, are also available on EOG's website at Key Financial ResultsIn millions of USD, except per-share, per-Boe and ratio dataGAAP 2Q 20251Q 20254Q 20243Q 20242Q 2024Total Revenue 5,4785,6695,5855,9656,025Net Income 1,3451,4631,2511,6731,690Net Income Per Share 2.462.652.232.952.95Net Cash Provided by Operating Activities 2,0322,2892,7633,5882,889Total Expenditures 1,8831,5461,4461,5731,682Current and Long-Term Debt 4,2364,7444,7523,7763,784Cash and Cash Equivalents 5,2166,5997,0926,1225,431Debt-to-Total Capitalization 12.7 %13.8 %13.9 %11.3 %11.5 %Cash Operating Costs ($/Boe) 10.0510.3110.1510.1510.11 Non-GAAP Adjusted Net Income 1,2681,5861,5351,6441,807Adjusted Net Income Per Share 2.322.872.742.893.16Adjusted CFO1 2,4962,8132,6352,9883,042Capital Expenditures 1,5231,4841,3581,4971,668Free Cash Flow 9731,3291,2771,4911,374Net Debt (980)(1,855)(2,340)(2,346)(1,647)Net Debt-to-Total Capitalization (3.5 %)(6.7 %)(8.7 %)(8.6 %)(6.0 %)Cash Operating Costs ($/Boe)2,3 9.9410.3110.1510.0510.11Second Quarter Highlights Earned adjusted net income of $1.3 billion, or $2.32 per share Generated $1.0 billion of free cash flow Paid $528 million in regular dividends and repurchased $600 million of shares Oil, NGLs and natural gas production above guidance midpoints Capital expenditures and per-unit operating costs better than guidance midpoints Completed $3.5 billion debt offering to fund the acquisition of Encino Acquisition Partners (Encino) 2025 Guidance Update Updated 2025 guidance after close of Encino acquisition Volumes and Capital Expenditures2Q 2025Volumes 2Q 2025Guidance Midpoint1Q 20254Q 20243Q 20242Q 2024Crude Oil and Condensate (MBod) 504.2502.1502.1494.6493.0490.7Natural Gas Liquids (MBbld) 258.4251.0241.7252.5254.3244.8Natural Gas (MMcfd) 2,2292,1702,0802,0921,9701,872Total Crude Oil Equivalent (MBoed) 1,134.11,114.81,090.41,095.71,075.71,047.5 Capital Expenditures ($MM) 1,5231,5501,4841,3581,4971,668From Ezra Yacob, Chairman and Chief Executive Officer"EOG delivered excellent second quarter results, with oil, gas, and NGL volumes exceeding the midpoints of our guidance. At the same time, we maintained our focus on cost discipline, with capital expenditures, cash operating costs, and DD&A all coming in below guidance. Strong operational execution across our multi-basin portfolio continues to be the foundation of our success. "Our operational excellence translated into strong financial performance. EOG generated $973 million in free cash flow during the quarter. We continued to deliver on our cash return commitment by returning $1.1 billion to shareholders, including $600 million of share repurchases. The regular dividend remains our top cash return priority. The 5% increase in our regular quarterly dividend, announced in tandem with the Encino acquisition, reflects both our continued confidence in our business and the positive impact we expect from the transaction. "With the close of the Encino acquisition, the Utica is now positioned as a foundational asset for EOG. We have updated our full year 2025 guidance, which reflects both capital discipline and our high conviction in the quality and potential of this asset. Our focus is on optimizing the development of the play as we integrate Encino with our operations. "EOG has never been better positioned to create long-term value for shareholders. The expansion of our portfolio through the Encino acquisition, our entry into Bahrain and the UAE, as well as strong exploration progress across our domestic portfolio and in Trinidad, has significantly enhanced our industry-leading asset base. We continue to improve our resource base while also maintaining one of the strongest balance sheets in the industry. Our multi- basin portfolio, operational excellence, and financial strength provide us unmatched flexibility to deliver high returns and significant cash return to shareholders through commodity price cycles." Previously Announced Regular Dividend and Second Quarter Share RepurchasesOn May 30, 2025, the Board of Directors declared a dividend of $1.02 per share on EOG's common stock. The dividend will be payable on October 31, 2025, to shareholders of record as of October 17, 2025. The indicated annual rate is $4.08 per share. During the second quarter, the company repurchased 5.4 million shares for $600 million under its share repurchase authorization. EOG has $4.5 billion remaining on its current share buyback authorization. 2025 Guidance 2025 Guidance Update Full year guidance has been updated after the close of the Encino acquisition. The revised outlook also incorporates strong year-to-date operational performance and the impact of recently enacted U.S. tax legislation. Total capital expenditures for 2025 are now expected to range from $6.2 to $6.4 billion delivering full year average oil production of 521 MBod and average total production of 1,224 MBoed. Second Quarter 2025 Financial Performance Prices Crude oil, NGL and natural gas prices decreased in 2Q compared with 1Q Volumes Oil production of 504,200 Bopd was above the midpoint of the guidance range and up from 1Q NGL production was above the midpoint of the guidance range and up 7% from 1Q Natural gas production was above the midpoint of the guidance range and up 7% from 1Q Total company equivalent production was above the midpoint of the guidance range and increased 4% from 1Q Per-Unit Costs LOE, GP&T, DD&A and non-GAAP G&A costs decreased in 2Q compared to 1Q. Encino acquisition-related costs increased GAAP G&A costs in 2Q compared to 1Q Hedges Mark-to-market hedge gains increased GAAP earnings per share in 2Q compared with 1Q Decreased cash paid to settle hedges increased adjusted non-GAAP earnings per share in 2Q compared with 1Q Free Cash Flow Adjusted cash flow from operations was $2.5 billion Incurred $1.5 billion of capital expenditures This resulted in $1.0 billion of free cash flow Cash Return and Working Capital Paid $528 million in regular dividends Repurchased $600 million of stock Repaid $500 million of Senior Notes upon maturity Acquired Eagle Ford bolt-on acreage for approximately $270 million Second Quarter 2025 Operating Performance Lease and Well QoQ: Decreased primarily due to lower maintenance costs and water handling expenses Guidance Midpoint: Lower primarily due to lower maintenance costs, water handling expenses and workover expenses General and Administrative QoQ: Decreased primarily due to lower professional fees Guidance Midpoint: Lower primarily due to lower professional fees Gathering, Processing and Transportation Costs QoQ: Decreased primarily due to lower natural gas gathering and processing fees and operating expenses Guidance Midpoint: Lower primarily due to lower natural gas gathering and processing fees and compression fuel-related costs Depreciation, Depletion and Amortization QoQ: Decreased primarily due to well mix Guidance Midpoint: Lower primarily due to well mix Second Quarter 2025 Results vs Guidance(Unaudited)See "Endnotes" below for related discussion and definitions. 2Q 20252Q 2025Guidance Midpoint7Variance1Q 20254Q 20243Q 20242Q 2024 Crude Oil and Condensate Volumes (MBod)United States 503.1501.31.8500.9493.5491.8490.1 Trinidad 1.10.80.31.21.11.20.6 Total 504.2502.12.1502.1494.6493.0490.7 Natural Gas Liquids Volumes (MBbld)Total 258.4251.07.4241.7252.5254.3244.8 Natural Gas Volumes (MMcfd)United States 1,9771,930471,8341,8401,7451,668 Trinidad 25224012246252225204 Total 2,2292,170592,0802,0921,9701,872 Total Crude Oil Equivalent Volumes (MBoed) 1,134.11,114.819.31,090.41,095.71,075.71,047.5 Total MMBoe 103.2101.41.898.1100.899.095.3 Benchmark PriceOil (WTI) ($/Bbl) 63.7171.4270.2875.1680.55 Natural Gas (HH) ($/Mcf) 3.443.662.792.161.89 Crude Oil and Condensate - above (below) WTI8 ($/Bbl)United States 1.131.30(0.17)1.481.401.792.16 Trinidad (9.21)(9.50)0.29(10.30)(9.81)(12.01)(9.80) Natural Gas Liquids - Realizations as % of WTITotal 35.6 %34.0 %1.6 %36.8 %33.9 %29.8 %28.7 % Natural Gas - above (below) NYMEX Henry Hub9 ($/Mcf)United States (0.57)(0.45)(0.12)(0.30)(0.40)(0.32)(0.32) Natural Gas Realizations ($/Mcf)Trinidad 3.653.600.053.783.863.683.48 Total Expenditures (GAAP) ($MM) 1,8831,5461,4461,5731,682 Capital Expenditures (non-GAAP) ($MM) 1,5231,550(27)1,4841,3581,4971,668 Operating Unit Costs ($/Boe)Lease and Well 3.844.15(0.31)4.093.913.964.09 Gathering, Processing and Transportation Costs6 4.414.55(0.14)4.484.374.504.44 General and Administrative (GAAP) 1.801.750.051.741.871.691.58 General and Administrative (non-GAAP)2,3 1.691.75(0.06)1.741.871.591.58 Cash Operating Costs (GAAP) 10.0510.45(0.40)10.3110.1510.1510.11 Cash Operating Costs (non-GAAP)2,3 9.9410.45(0.51)10.3110.1510.0510.11 Depreciation, Depletion and Amortization 10.2010.30(0.10)10.3210.1110.4210.32 Expenses ($MM)Exploration and Dry Hole 85701575604339 Impairment (GAAP) 39442761581 Impairment (excluding certain impairments (non-GAAP)10 2870(42)44231546 Capitalized Interest 1112(1)12131210 Net Interest (GAAP) 5143847383136 Net Interest (non-GAAP)5 4543247383136 TOTI (% of revenues from sales of crude oil and condensate, NGLs and natural gas)(GAAP) 7.3 %8.0 %(0.7 %)7.6 %6.8 %6.5 %7.5 % (non-GAAP)3 7.3 %8.0 %(0.7 %)7.6 %6.8 %7.2 %7.5 % Income TaxesEffective Rate 23.2 %22.5 %0.7 %22.1 %23.0 %21.6 %21.7 % Current Tax Expense ($MM) 30126041370454240341 Third Quarter and Full-Year 2025 Guidance11 (Unaudited)See "Endnotes" below for related discussion and definitions. 3Q 20253Q 2025FY 2025FY 2025 Guidance RangeMidpointGuidance RangeMidpointCrude Oil and Condensate Volumes (MBod) United States 528.7 - 533.3531.0517.6 - 521.4519.5Trinidad 1.2 - 1.61.41.1 - 1.51.3Total 529.9 - 534.9532.4518.7 - 522.9520.8Natural Gas Liquids Volumes (MBbld) Total 297.5 - 312.5305.0279.0 - 289.0284.0Natural Gas Volumes (MMcfd) United States 2,475 - 2,5752,5252,240 - 2,3402,290Trinidad 200 - 220210215 - 235225Total 2,675 - 2,7952,7352,455 - 2,5752,515Crude Oil Equivalent Volumes (MBoed) United States 1,238.7 - 1,275.01,256.91,169.9 - 1,200.41,185.2Trinidad 34.5 - 38.336.436.9 - 40.738.8Total 1,273.2 - 1,313.31,293.31,206.8 - 1,241.11,224.0Crude Oil and Condensate - above (below) WTI8 ($/Bbl)United States 0.05 - 1.550.80(0.15) - 1.850.85Trinidad (5.75) - (4.25)(5.00)(8.00) - (6.00)(7.00)Natural Gas Liquids - Realizations as % of WTITotal 29.0 % - 39.0 %34.0 %30.0 % - 40.0 %35.0 % Natural Gas - above (below) NYMEX Henry Hub9 ($/Mcf)United States (0.75) - (0.05)(0.40)(1.40) - 0.60(0.40)Natural Gas Realizations ($/Mcf) Trinidad 3.25 - 3.953.603.10 - 4.103.60 Capital Expenditures12 ($MM) 1,600 - 1,7001,6506,200 - 6,4006,300 Operating Unit Costs ($/Boe) Lease and Well 3.45 - 3.953.703.55 - 4.053.80Gathering, Processing and Transportation Costs6 4.85 - 5.355.104.65 - 5.154.90General and Administrative 1.35 - 1.651.501.50 - 1.801.65Cash Operating Costs 9.65 - 10.9510.309.70 - 11.0010.35Depreciation, Depletion and Amortization 9.35 - 10.359.859.55 - 10.5510.05 Expenses ($MM) Exploration and Dry Hole 55 - 9575270 - 310290Impairment (excluding certain impairments)10 30 - 11070180 - 260220Capitalized Interest 19 - 232168 - 7270Net Interest 81 - 8583248 - 252250 TOTI (% of revenues from sales of crude oil and condensate, NGLs and natural gas) 6.5 % - 8.5 %7.5 %6.5 % - 8.5 %7.5 %Income Taxes Effective Rate 18.0 % - 23.0 %20.5 %20.0 % - 25.0 %22.5 %Current Tax Expense ($MM) 130 - 2301801,040 - 1,2401,140Second Quarter 2025 Results WebcastFriday, August 8, 2025, 9:00 a.m. Central time (10:00 a.m. Eastern time) Webcast will be available on EOG's website for one year. About EOGEOG Resources, Inc. (NYSE: EOG) is one of the largest crude oil and natural gas exploration and production companies in the United States with proved reserves in the United States and Trinidad. To learn more visit Investor ContactsPearce Hammond 713-571-4684Neel Panchal 713-571-4884Shelby O'Connor 713-571-4560 Media ContactKimberly Ehmer 713-571-4676 Endnotes 1) Cash flow from operations before changes in working capital and certain acquisition-related costs. 2) Cash Operating Costs consist of LOE, GP&T and G&A. Excludes Encino acquisition-related G&A costs of $12 million for 2Q 2025, as reflected in the accompanying reconciliation schedules (see "Revenues, Costs and Margins Per Barrel of Oil Equivalent"). The per-Boe impact of such Encino acquisition–related costs on G&A and total Cash Operating Costs for 2Q 2025 was ($0.11) as set forth in "Second Quarter 2025 Results vs Guidance" above. G&A per Boe (GAAP) for 2Q 2025 was $1.80. 3) Cash Operating Costs consist of LOE, GP&T and G&A. TOTI (% of revenues from sales of crude oil and condensate, NGLs and natural gas) (non-GAAP) and G&A (non-GAAP) for 3Q 2024 exclude a state severance tax refund and related consulting fees, as reflected in the accompanying reconciliation schedules (see "Revenues, Costs and Margins Per Barrel of Oil Equivalent"). The per-Boe impact of such consulting fees on G&A and total Cash Operating Costs for 3Q 2024 was $(0.10) as set forth in "Second Quarter 2025 Results vs Guidance" above. 4) Includes gathering, processing and marketing revenue, gains (losses) on asset dispositions (for GAAP earnings per share only), other revenue, exploration costs, dry hole costs, impairments and marketing costs, taxes other than income, other income (expense), interest expense, the impact of changes in the effective income tax rate and the impact of share repurchases on diluted shares. 5) Net interest expense (non-GAAP) excludes Encino acquisition-related financing commitment costs of $6 million for 2Q 2025. 6) Effective January 1, 2024, EOG combined Transportation Costs and Gathering and Processing Costs into one line item titled Gathering, Processing and Transportation Costs. This presentation has been conformed for all periods presented and had no impact on previously reported Net Income. 7) GAAP and non-GAAP distinctions apply solely to actual results and do not pertain to EOG's second quarter 2025 guidance midpoint disclosure. 8) EOG bases United States and Trinidad crude oil and condensate price differentials upon the West Texas Intermediate crude oil price at Cushing, Oklahoma, using the simple average of the NYMEX settlement prices for each trading day within the applicable calendar month. 9) EOG bases United States natural gas price differentials upon the natural gas price at Henry Hub, Louisiana, using the NYMEX Last Day Settle price for each of the applicable months. 10) In general, EOG excludes impairments which are (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets). EOG believes excluding these impairments from total impairment costs is appropriate and provides useful information to investors, as such impairments were caused by factors outside of EOG's control (versus, for example, impairments that are due to EOG's proved oil and gas properties not being as productive as it originally estimated). 11) The forecast items for the third quarter and full year 2025 set forth above for EOG are based on currently available information and expectations as of the date of this press release. EOG undertakes no obligation, other than as required by applicable law, to update or revise this forecast, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise. This forecast, which should be read in conjunction with this press release and EOG's related Current Report on Form 8-K filing, replaces and supersedes any previously issued guidance or forecast. 12) The forecast includes expenditures for Exploration and Development Drilling, Facilities, Leasehold Acquisitions, Capitalized Interest, Dry Hole Costs and Other Property, Plant and Equipment. The forecast excludes Property Acquisitions, Asset Retirement Costs, Non-Cash Exchanges and Transactions and exploration costs incurred as operating expenses. GlossaryAcq Acquisitions Adjusted CFO Cash flow from operations before changes in working capital and certain acquisition-related costs ATROR After-tax rate of return Bbl Barrel Bn Billion Boe Barrels of oil equivalent Bopd Barrels of oil per day CAGR Compound annual growth rate Capex Capital expenditures CO2e Carbon dioxide equivalent DD&A Depreciation, Depletion and Amortization Disc Discoveries Divest Divestitures EPS Earnings per share Ext Extensions GAAP Generally Accepted Accounting Principles G&A General and administrative expense G&P Gathering and processing GHG Greenhouse gas GP&T Gathering, processing & transportation expense HH Henry Hub LOE Lease operating expense, or lease and well expense MBbld Thousand barrels of liquids per day MBod Thousand barrels of oil per day MBoe Thousand barrels of oil equivalent MBoed Thousand barrels of oil equivalent per day Mcf Thousand cubic feet of natural gas MMBoe Million barrels of oil equivalent MMcfd Million cubic feet of natural gas per day NGLs Natural gas liquids NYMEX U.S. New York Mercantile Exchange OTP Other than price QoQ Quarter over quarter TOTI Taxes other than income USD United States dollar WTI West Texas Intermediate YoY Year over year $MM Million United States dollars $/Bbl U.S. Dollars per barrel $/Boe U.S. Dollars per barrel of oil equivalent $/Mcf U.S. Dollars per thousand cubic feet This press release and any accompanying disclosures may include 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 facts, including, among others, statements and projections regarding EOG's future financial position, operations, performance, business strategy, goals, returns and rates of return, budgets, reserves, levels of production, capital expenditures, operating costs and asset sales, statements regarding future commodity prices, statements regarding the plans and objectives of EOG's management for future operations and statements and projections regarding the strategic rationale for, and anticipated benefits of, EOG's acquisition of Encino Acquisition Partners, LLC (Encino) are forward-looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "aims," "ambition," "initiative," "goal," "may," "will," "focused on," "should" and "believe" or the negative of those terms or other variations or comparable terminology to identify its forward-looking statements. In particular, statements, express or implied, concerning (i) EOG's future financial or operating results and returns, (ii) EOG's ability to replace or increase reserves, increase production, generate returns and rates of return, replace or increase drilling locations, reduce or otherwise control drilling, completion and operating costs and capital expenditures, generate cash flows, pay down or refinance indebtedness, achieve, reach or otherwise meet initiatives, plans, goals, ambitions or targets with respect to emissions, other environmental matters or safety matters, pay and/or increase regular and/or special dividends or repurchase shares or (iii) the successful integration of Encino's assets and operations or the strategic rationale for, or anticipated benefits of, EOG's acquisition of Encino, in each case are forward-looking statements. Forward-looking statements are not guarantees of performance. Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that such assumptions are accurate or will prove to have been correct or that any of such expectations will be achieved (in full or at all) or will be achieved on the expected or anticipated timelines. Moreover, EOG's forward-looking statements may be affected by known, unknown or currently unforeseen risks, events or circumstances that may be outside EOG's control. Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's forward-looking statements include, among others: the timing, magnitude and duration of changes in prices for, supplies of, and demand for, crude oil and condensate, natural gas liquids (NGLs), natural gas and related commodities; the extent to which EOG is successful in its efforts to acquire or discover additional reserves; the extent to which EOG is successful in its efforts to (i) economically develop its acreage in, (ii) produce reserves and achieve anticipated production levels and rates of return from, (iii) decrease or otherwise control its drilling, completion and operating costs and capital expenditures related to, and (iv) maximize reserve recoveries from, its existing and future crude oil and natural gas exploration and development projects and associated potential and existing drilling locations; the success of EOG's cost-mitigation initiatives and actions in offsetting the impact of any inflationary or other pressures on EOG's operating costs and capital expenditures; the extent to which EOG is successful in its efforts to market its production of crude oil and condensate, NGLs and natural gas; security threats, including cybersecurity threats and disruptions to our business and operations from breaches of our information technology systems, physical breaches of our facilities and other infrastructure or breaches of the information technology systems, facilities and infrastructure of third parties with which we transact business, and enhanced regulatory focus on the prevention of, and disclosure requirements relating to, cyber incidents; the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, storage, transportation, refining, liquefaction and export facilities and equipment; the availability, cost, terms and timing of issuance or execution of mineral licenses, concessions and leases and governmental and other permits and rights-of-way, and EOG's ability to retain mineral licenses, concessions and leases; the impact of, and changes in, government policies, laws and regulations, including climate change-related regulations, policies and initiatives (for example, with respect to air emissions); tax laws and regulations (including, but not limited to, carbon tax or other emissions-related legislation); environmental, health and safety laws and regulations relating to disposal of produced water, drilling fluids and other wastes, hydraulic fracturing and access to and use of water; laws and regulations affecting the leasing of acreage and permitting for oil and gas drilling and the calculation of royalty payments in respect of oil and gas production; laws and regulations imposing additional permitting and disclosure requirements, additional operating restrictions and conditions or restrictions on drilling and completion operations and on the transportation of crude oil, NGLs and natural gas; laws and regulations with respect to financial and other derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities; the impact of climate change-related legislation, policies and initiatives; climate change-related political, social and shareholder activism; and physical, transition and reputational risks and other potential developments related to climate change; the extent to which EOG is able to successfully and economically develop, implement and carry out its emissions and other environmental or safety-related initiatives and achieve its related targets, goals, ambitions and initiatives; EOG's failure to realize, in full or at all, the anticipated benefits of its acquisition of Encino and/or business disruptions resulting from the acquisition (e.g., relating to the integration of Encino's assets and operations into EOG's operations) that could harm EOG's business operations (including current plans and operations and the diversion of management's attention from EOG's ongoing business operations); EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, identify and resolve existing and potential issues with respect to such properties and accurately estimate reserves, production, drilling, completion and operating costs and capital expenditures with respect to such properties; the extent to which EOG's third-party-operated crude oil and natural gas properties are operated successfully, economically and in compliance with applicable laws and regulations; competition in the oil and gas exploration and production industry for the acquisition of licenses, concessions, leases and properties; the availability and cost of, and competition in the oil and gas exploration and production industry for, employees, labor and other personnel, facilities, equipment, materials (such as water, sand, fuel and tubulars) and services; the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise; weather and natural disasters, including its impact on crude oil and natural gas demand, and related delays in drilling and in the installation and operation (by EOG or third parties) of production, gathering, processing, refining, liquefaction, compression, storage, transportation, and export facilities; the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their obligations to EOG; EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all, and to otherwise satisfy its capital expenditure requirements; the extent to which EOG is successful in its completion of planned asset dispositions; the extent and effect of any hedging activities engaged in by EOG; the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions; the economic and financial impact of epidemics, pandemics or other public health issues; geopolitical factors and political conditions and developments around the world (such as the imposition of tariffs or trade or other economic sanctions, political instability and armed conflicts), including in the areas in which EOG operates; the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage; and the other factors described under ITEM 1A, Risk Factors of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2024 and any updates to those factors set forth in EOG's subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K. In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and, if any of such events do, we may not have anticipated the timing of their occurrence or the duration or extent of their impact on our actual results. Accordingly, you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the date made, and EOG undertakes no obligation, other than as required by applicable law, to update or revise its forward-looking statements, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise. Historical Non-GAAP Financial Measures:Reconciliation schedules and definitions for the historical non-GAAP financial measures included or referenced herein as well as related discussion can be found on the EOG website at Cautionary Notice Regarding Forward-Looking Non-GAAP Financial Measures:In addition, this press release and any accompanying disclosures may include or reference certain forward-looking, non-GAAP financial measures, such as free cash flow, adjusted cash flow from operations and return on capital employed, and certain related estimates regarding future performance, commodity prices and operating and financial results. Because we provide these measures on a forward-looking basis, we cannot reliably or reasonably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future changes in working capital and future impairments. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking, non-GAAP financial measures to the respective most directly comparable forward-looking GAAP financial measures without unreasonable efforts. The unavailable information could have a significant impact on our ultimate results. However, management believes these forward-looking, non-GAAP measures may be a useful tool for the investment community in comparing EOG's forecasted financial performance to the forecasted financial performance of other companies in the industry. Any such forward-looking measures and estimates are intended to be illustrative only and are not intended to reflect the results that EOG will necessarily achieve for the period(s) presented; EOG's actual results may differ materially from such measures and estimates. Oil and Gas Reserves:The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose not only "proved" reserves (i.e., quantities of oil and gas that are estimated to be recoverable with a high degree of confidence), but also "probable" reserves (i.e., quantities of oil and gas that are as likely as not to be recovered) as well as "possible" reserves (i.e., additional quantities of oil and gas that might be recovered, but with a lower probability than probable reserves). Statements of reserves are only estimates and may not correspond to the ultimate quantities of oil and gas recovered. Any reserve or resource estimates provided in this press release or any accompanying disclosures that are not specifically designated as being estimates of proved reserves may include "potential" reserves, "resource potential" and/or other estimated reserves or estimated resources not necessarily calculated in accordance with, or contemplated by, the SEC's latest reserve reporting guidelines. Investors are urged to consider closely the disclosure in EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2024 (and any updates to such disclosure set forth in EOG's subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K), available from EOG at P.O. Box 4362, Houston, Texas 77210-4362 (Attn: Investor Relations). You can also obtain this report from the SEC by calling 1-800-SEC-0330 or from the SEC's website at Income Statements In millions of USD, except share data (in millions) and per share data (Unaudited)202420251st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year1st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year Operating Revenues and OtherCrude Oil and Condensate 3,480 3,692 3,488 3,261 13,9213,293 2,974 6,267 Natural Gas Liquids 513 515 524 554 2,106572 534 1,106 Natural Gas 382 303 372 494 1,551637 600 1,237 Gains (Losses) on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net 237 (47) 79 (65) 204(191) 107 (84) Gathering, Processing and Marketing 1,459 1,519 1,481 1,341 5,8001,340 1,247 2,587 Gains (Losses) on Asset Dispositions, Net 26 20 (7) (23) 16(1) — (1) Other, Net 26 23 28 23 10019 16 35 Total 6,123 6,025 5,965 5,585 23,6985,669 5,478 11,147 Operating ExpensesLease and Well 396 390 392 394 1,572401 396 797 Gathering, Processing and Transportation Costs 413 423 445 441 1,722440 455 895 Exploration Costs 45 34 43 52 17441 74 115 Dry Hole Costs 1 5 — 8 1434 11 45 Impairments 19 81 15 276 39144 39 83 Marketing Costs 1,404 1,490 1,500 1,323 5,7171,325 1,216 2,541 Depreciation, Depletion and Amortization 1,074 984 1,031 1,019 4,1081,013 1,053 2,066 General and Administrative 162 151 167 189 669171 186 357 Taxes Other Than Income 338 337 283 291 1,249341 301 642 Total 3,852 3,895 3,876 3,993 15,6163,810 3,731 7,541 Operating Income 2,271 2,130 2,089 1,592 8,0821,859 1,747 3,606 Other Income, Net 62 66 76 70 27465 55 120 Income Before Interest Expense and Income Taxes 2,333 2,196 2,165 1,662 8,3561,924 1,802 3,726 Interest Expense, Net 33 36 31 38 13847 51 98 Income Before Income Taxes 2,300 2,160 2,134 1,624 8,2181,877 1,751 3,628 Income Tax Provision 511 470 461 373 1,815414 406 820 Net Income 1,789 1,690 1,673 1,251 6,4031,463 1,345 2,808 Dividends Declared per Common Share 0.9100 0.9100 0.9100 0.9750 3.70500.9750 1.9950 2.9700 Net Income Per ShareBasic 3.11 2.97 2.97 2.25 11.312.66 2.48 5.13 Diluted 3.10 2.95 2.95 2.23 11.252.65 2.46 5.11 Average Number of Common SharesBasic 575 569 564 557 566550 543 547 Diluted 577 572 568 561 569553 546 549 Volumes and Prices (Unaudited)202420251st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year1st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year Crude Oil and Condensate Volumes (MBbld) (A)United States 486.8 490.1 491.8 493.5 490.6500.9 503.1 502.0 Trinidad 0.6 0.6 1.2 1.1 0.81.2 1.1 1.1 Total 487.4 490.7 493.0 494.6 491.4502.1 504.2 503.1 Average Crude Oil and Condensate Prices ($/Bbl) (B)United States $ 78.46 $ 82.71 $ 76.95 $ 71.68 $ 77.42$ 72.90 $ 64.84 $ 68.84 Trinidad 67.50 70.75 63.15 60.47 64.4361.12 54.50 57.84 Composite 78.45 82.69 76.92 71.66 77.4072.87 64.82 68.81 Natural Gas Liquids Volumes (MBbld) (A)United States 231.7 244.8 254.3 252.5 245.9241.7 258.4 250.1 Total 231.7 244.8 254.3 252.5 245.9241.7 258.4 250.1 Average Natural Gas Liquids Prices ($/Bbl) (B)United States $ 24.32 $ 23.11 $ 22.42 $ 23.85 $ 23.40$ 26.29 $ 22.70 $ 24.42 Composite 24.32 23.11 22.42 23.85 23.4026.29 22.70 24.42 Natural Gas Volumes (MMcfd) (A)United States 1,658 1,668 1,745 1,840 1,7281,834 1,977 1,906 Trinidad 200 204 225 252 220246 252 249 Total 1,858 1,872 1,970 2,092 1,9482,080 2,229 2,155 Average Natural Gas Prices ($/Mcf) (B)United States $ 2.10 $ 1.57 $ 1.84 $ 2.39 $ 1.99$ 3.36 $ 2.87 $ 3.10 Trinidad 3.54 3.48 3.68 3.86 3.653.78 3.65 3.71 Composite 2.26 1.78 2.05 2.57 2.173.41 2.96 3.17 Crude Oil Equivalent Volumes (MBoed) (C)United States 994.7 1,013.0 1,037.1 1,052.7 1,024.51,048.3 1,090.9 1,069.7 Trinidad 34.1 34.5 38.6 43.0 37.642.1 43.2 42.7 Total 1,028.8 1,047.5 1,075.7 1,095.7 1,062.11,090.4 1,134.1 1,112.4 Total MMBoe (C) 93.6 95.3 99.0 100.8 388.798.1 103.2 201.3 (A) Thousand barrels per day or million cubic feet per day, as applicable. (B) Dollars per barrel or per thousand cubic feet, as applicable. Excludes the impact of financial commodity and other derivative instruments (see Note 10 to the Condensed Consolidated Financial Statements in EOG's Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2025). (C) Thousand barrels of oil equivalent per day or million barrels of oil equivalent, as applicable; includes crude oil and condensate, NGLs and natural gas. Crude oil equivalent volumes are determined using a ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas. MMBoe is calculated by multiplying the MBoed amount by the number of days in the period and then dividing that amount by one thousand. Balance Sheets In millions of USD (Unaudited)20242025MAR JUN SEP DECMAR JUN SEP DEC Current AssetsCash and Cash Equivalents 5,292 5,431 6,122 7,0926,599 5,216 Accounts Receivable, Net 2,688 2,657 2,545 2,6502,621 2,504 Inventories 1,154 1,069 1,038 985897 934 Assets from Price Risk Management Activities 110 4 — —— — Other (A) 684 642 460 503563 591 Total 9,928 9,803 10,165 11,23010,680 9,245 Property, Plant and EquipmentOil and Gas Properties (Successful Efforts Method) 73,356 74,615 75,887 77,09178,432 80,139 Other Property, Plant and Equipment 5,768 6,078 6,314 6,4186,510 6,616 Total Property, Plant and Equipment 79,124 80,693 82,201 83,50984,942 86,755 Less: Accumulated Depreciation, Depletion and Amortization (46,047) (47,049) (48,075) (49,297)(50,310) (51,394) Total Property, Plant and Equipment, Net 33,077 33,644 34,126 34,21234,632 35,361 Deferred Income Taxes 38 44 42 3944 39 Other Assets 1,753 1,733 1,818 1,7051,626 1,639 Total Assets 44,796 45,224 46,151 47,18646,982 46,284 Current LiabilitiesAccounts Payable 2,389 2,436 2,290 2,4642,353 2,266 Accrued Taxes Payable 786 600 855 1,007668 348 Dividends Payable 523 516 513 539534 1,081 Liabilities from Price Risk Management Activities — 8 32 116276 85 Current Portion of Long-Term Debt 34 534 34 5321,280 778 Current Portion of Operating Lease Liabilities 318 303 338 315318 360 Other 223 231 344 381290 257 Total 4,273 4,628 4,406 5,3545,719 5,175 Long-Term Debt 3,757 3,250 3,742 4,2203,464 3,458 Other Liabilities 2,533 2,456 2,480 2,3952,368 2,398 Deferred Income Taxes 5,597 5,731 5,949 5,8665,915 6,015 Commitments and ContingenciesStockholders' EquityCommon Stock, $0.01 Par 206 206 206 206206 206 Additional Paid in Capital 6,188 6,219 6,058 6,0906,095 6,153 Accumulated Other Comprehensive Loss (8) (8) (9) (4)(4) (7) Retained Earnings 23,897 25,071 26,231 26,94127,869 28,131 Common Stock Held in Treasury (1,647) (2,329) (2,912) (3,882)(4,650) (5,245) Total Stockholders' Equity 28,636 29,159 29,574 29,35129,516 29,238 Total Liabilities and Stockholders' Equity 44,796 45,224 46,151 47,18646,982 46,284 (A) Effective October 1, 2024, EOG combined Income Taxes Receivable into the Other line item. This presentation has been conformed for all periods presented and had no impact on previously reported Total Assets. Cash Flow Statements In millions of USD (Unaudited) 202420251st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year1st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year Cash Flows from Operating ActivitiesReconciliation of Net Income to Net Cash Provided by Operating Activities:Net Income 1,789 1,690 1,673 1,251 6,4031,463 1,345 2,808 Items Not Requiring (Providing) CashDepreciation, Depletion and Amortization 1,074 984 1,031 1,019 4,1081,013 1,053 2,066 Impairments 19 81 15 276 39144 39 83 Stock-Based Compensation Expenses 45 45 58 51 19950 53 103 Deferred Income Taxes 199 128 220 (80) 46744 105 149 (Gains) Losses on Asset Dispositions, Net (26) (20) 7 23 (16)1 — 1 Other, Net 9 3 2 3 1711 11 22 Dry Hole Costs 1 5 — 8 1434 11 45 Mark-to-Market Financial Commodity and Other Derivative Contracts (Gains) Losses, Net (237) 47 (79) 65 (204)191 (107) 84 Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts 55 79 61 19 214(38) (24) (62) Changes in Components of Working Capital and Other Assets and LiabilitiesAccounts Receivable 58 33 109 (99) 10148 122 170 Inventories 117 75 30 37 25976 (45) 31 Accounts Payable (58) 29 (159) 152 (36)(129) (107) (236) Accrued Taxes Payable 319 (185) 256 151 541(339) (321) (660) Other Assets (161) 42 197 (34) 44(43) (43) (86) Other Liabilities (71) (20) 108 6 23(96) (52) (148) Changes in Components of Working Capital Associated with Investing Activities (229) (127) 59 (85) (382)(41) (8) (49) Net Cash Provided by Operating Activities 2,903 2,889 3,588 2,763 12,1432,289 2,032 4,321 Investing Cash FlowsAdditions to Oil and Gas Properties (1,485) (1,357) (1,263) (1,248) (5,353)(1,381) (1,699) (3,080) Additions to Other Property, Plant and Equipment (350) (313) (239) (117) (1,019)(102) (94) (196) Proceeds from Sales of Assets 9 10 — 4 2312 4 16 Changes in Components of Working Capital Associated with Investing Activities 229 127 (59) 85 38241 8 49 Net Cash Used in Investing Activities (1,597) (1,533) (1,561) (1,276) (5,967)(1,430) (1,781) (3,211) Financing Cash FlowsLong-Term Debt Borrowings — — — 985 985— — — Long-Term Debt Repayments — — — — —— (500) (500) Dividends Paid (525) (520) (533) (509) (2,087)(538) (528) (1,066) Treasury Stock Purchased (759) (699) (795) (993) (3,246)(806) (602) (1,408) Proceeds from Stock Options Exercised and Employee Stock Purchase Plan — 11 — 11 22— 11 11 Debt Issuance and Other Financing Costs — — — (2) (2)— (7) (7) Repayment of Finance Lease Liabilities (8) (9) (8) (8) (33)(8) (9) (17) Net Cash Used in Financing Activities (1,292) (1,217) (1,336) (516) (4,361)(1,352) (1,635) (2,987) Effect of Exchange Rate Changes on Cash — – – (1) (1)— 1 1 Increase (Decrease) in Cash and Cash Equivalents 14 139 691 970 1,814(493) (1,383) (1,876) Cash and Cash Equivalents at Beginning of Period 5,278 5,292 5,431 6,122 5,2787,092 6,599 7,092 Cash and Cash Equivalents at End of Period 5,292 5,431 6,122 7,092 7,0926,599 5,216 5,216 Non-GAAP Financial MeasuresTo supplement the presentation of its financial results prepared in accordance with generally accepted accounting principles in the United States of America (GAAP), EOG's quarterly earnings releases and related conference calls, accompanying investor presentation slides and presentation slides for investor conferences contain certain financial measures that are not prepared or presented in accordance with GAAP. These non-GAAP financial measures may include, but are not limited to, Adjusted Net Income (Loss), Adjusted Cash Flow from Operations, Free Cash Flow, Net Debt and related statistics.A reconciliation of each of these measures to their most directly comparable GAAP financial measure and related discussion is included in the tables on the following pages and can also be found in the "Reconciliations & Guidance" section of the "Investors" page of the EOG website at further discussed in the tables on the following pages, EOG believes these measures may be useful to investors who follow the practice of some industry analysts who make certain adjustments to GAAP measures (for example, to exclude non-recurring items) to facilitate comparisons to others in EOG's industry, and who utilize non-GAAP measures in their calculations of certain statistics (for example, return on capital employed and return on equity) used to evaluate EOG's believes that the non-GAAP measures presented, when viewed in combination with its financial results prepared in accordance with GAAP, provide a more complete understanding of the factors and trends affecting the company's performance. As is discussed in the tables on the following pages, EOG uses these non-GAAP measures for purposes of (i) comparing EOG's financial performance with the financial performance of other companies in the industry and (ii) analyzing EOG's financial performance across non-GAAP measures presented should not be considered in isolation, and should not be considered as a substitute for, or as an alternative to, EOG's reported Net Income (Loss), Long-Term Debt (including Current Portion of Long-Term Debt), Net Cash Provided by Operating Activities and other financial results calculated in accordance with GAAP. The non-GAAP measures presented should be read in conjunction with EOG's consolidated financial statements prepared in accordance with addition, because not all companies use identical calculations, EOG's presentation of non-GAAP measures may not be comparable to, and may be calculated differently from, similarly titled measures disclosed by other companies, including its peer companies. EOG may also change the calculation of one or more of its non-GAAP measures from time to time – for example, to account for changes in its business and operations or to more closely conform to peer company or industry analysts' ATRORThe calculation of EOG's direct after-tax rate of return (ATROR) is based on EOG's net estimated recoverable reserves for a particular well(s) or play, the estimated net present value of the future net cash flows from such reserves (for which EOG utilizes certain assumptions regarding future commodity prices and operating costs) and EOG's direct net costs incurred in drilling or acquiring such well(s). As such, EOG's direct ATROR for a particular well(s) or play cannot be calculated from EOG's consolidated financial statements. Adjusted Net Income In millions of USD, except share data (in millions) and per share data (Unaudited)The following tables adjust reported Net Income (Loss) (GAAP) to reflect actual net cash received from (payments for) settlements of financial commodity derivative contracts by eliminating the net unrealized mark-to-market (gains) losses from these and other derivative transactions, to eliminate the net (gains) losses on asset dispositions, to add back impairment charges related to certain of EOG's assets (which are generally (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets)), and to make certain other adjustments to exclude non-recurring and certain other items as further described below. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings to match hedge realizations to production settlement months and make certain other adjustments to exclude non-recurring and certain other items. EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.2Q 2025BeforeTaxIncome Tax ImpactAfterTaxDiluted Earnings per Share Reported Net Income (GAAP) 1,751(406)1,3452.46 Adjustments:Gains on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net (107)23(84)(0.16) Net Cash Payments for Settlements of Financial Commodity Derivative Contracts (1) (24)5(19)(0.03) Add: Certain Impairments 11—110.02 Add: Acquisition-related costs (2) 18(3)150.03 Adjustments to Net Income (102)25(77)(0.14) Adjusted Net Income (Non-GAAP) 1,649(381)1,2682.32 Average Number of Common SharesBasic 543 Diluted 546 (1) Consistent with its customary practice, in calculating Adjusted Net Income (non-GAAP), EOG subtracts from reported Net Income (GAAP) the total net cash paid for settlements of financial commodity derivative contracts during such period. For the three months ended June 30, 2025, such amount was $24 million. (2) Consists of Encino acquisition-related G&A costs ($12 million) and financing commitment costs ($6 million). Adjusted Net Income (Continued) In millions of USD, except share data (in millions) and per share data (Unaudited) 1Q 2025BeforeTaxIncome Tax ImpactAfterTaxDiluted Earnings per Share Reported Net Income (GAAP) 1,877(414)1,4632.65 Adjustments:Losses on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net 191(41)1500.26 Net Cash Payments for Settlements of Financial Commodity Derivative Contracts (1) (38)8(30)(0.05) Add: Losses on Asset Dispositions, Net 1230.01 Adjustments to Net Income 154(31)1230.22 Adjusted Net Income (Non-GAAP) 2,031(445)1,5862.87 Average Number of Common SharesBasic 550 Diluted 553 (1) Consistent with its customary practice, in calculating Adjusted Net Income (non-GAAP), EOG subtracts from reported Net Income (GAAP) the total net cash paid for settlements of financial commodity derivative contracts during such period. For the three months ended March 31, 2025, such amount was $38 million. Adjusted Net Income (Continued) In millions of USD, except share data (in millions) and per share data (Unaudited) 4Q 2024BeforeTaxIncome Tax ImpactAfterTaxDilutedEarnings per Share Reported Net Income (GAAP) 1,624(373)1,2512.23 Adjustments:Losses on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net 65(14)510.10 Net Cash Received from Settlements of Financial Commodity Derivative Contracts (1) 19(4)150.03 Add: Losses on Asset Dispositions, Net 23(4)190.03 Add: Certain Impairments 254(55)1990.35 Adjustments to Net Income 361(77)2840.51 Adjusted Net Income (Non-GAAP) 1,985(450)1,5352.74 Average Number of Common SharesBasic 557 Diluted 561 (1) Consistent with its customary practice, in calculating Adjusted Net Income (non-GAAP), EOG adds to reported Net Income (GAAP) the total net cash received from settlements of financial commodity derivative contracts during such period. For the three months ended December 31, 2024, such amount was $19 million. Adjusted Net Income (Continued) In millions of USD, except share data (in millions) and per share data (Unaudited) 3Q 2024BeforeTaxIncome Tax ImpactAfterTaxDiluted Earnings per Share Reported Net Income (GAAP) 2,134(461)1,6732.95 Adjustments:Gains on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net (79)17(62)(0.11) Net Cash Received from Settlements of Financial Commodity Derivative Contracts (1) 61(13)480.08 Add: Losses on Asset Dispositions, Net 7(2)50.01 Less: Severance Tax Refund (31)7(24)(0.04) Add: Severance Tax Consulting Fees 10(2)80.01 Less: Interest on Severance Tax Refund (5)1(4)(0.01) Adjustments to Net Income (37)8(29)(0.06) Adjusted Net Income (Non-GAAP) 2,097(453)1,6442.89 Average Number of Common SharesBasic 564 Diluted 568 (1) Consistent with its customary practice, in calculating Adjusted Net Income (non-GAAP), EOG adds to reported Net Income (GAAP) the total net cash received from settlements of financial commodity derivative contracts during such period. For the three months ended September 30, 2024, such amount was $61 million. Adjusted Net Income (Continued) In millions of USD, except share data (in millions) and per share data (Unaudited) 2Q 2024BeforeTaxIncome Tax ImpactAfterTaxDiluted Earnings per Share Reported Net Income (GAAP) 2,160(470)1,6902.95 Adjustments:Losses on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net 47(10)370.07 Net Cash Received from Settlements of Financial Commodity Derivative Contracts (1) 79(17)620.11 Less: Gains on Asset Dispositions, Net (20)5(15)(0.03) Add: Certain Impairments 35(2)330.06 Adjustments to Net Income 141(24)1170.21 Adjusted Net Income (Non-GAAP) 2,301(494)1,8073.16 Average Number of Common SharesBasic 569 Diluted 572 (1) Consistent with its customary practice, in calculating Adjusted Net Income (non-GAAP), EOG adds to reported Net Income (GAAP) the total net cash received from settlements of financial commodity derivative contracts during such period. For the three months ended June 30, 2024, such amount was $79 million. Adjusted Net Income (Continued) In millions of USD, except share data (in millions) and per share data (Unaudited) FY 2024BeforeTaxIncome Tax ImpactAfterTaxDiluted Earnings per Share Reported Net Income (GAAP) 8,218(1,815)6,40311.25 Adjustments:Gains on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net (204)44(160)(0.28) Net Cash Received from Settlements of Financial Commodity Derivative Contracts (1) 214(46)1680.30 Less: Gains on Asset Dispositions, Net (16)3(13)(0.02) Add: Certain Impairments 291(57)2340.41 Less: Severance Tax Refund (31)7(24)(0.04) Add: Severance Tax Consulting Fees 10(2)80.01 Less: Interest on Severance Tax Refund (5)1(4)(0.01) Adjustments to Net Income 259(50)2090.37 Adjusted Net Income (Non-GAAP) 8,477(1,865)6,61211.62 Average Number of Common Shares Basic 566 Diluted 569 (1) Consistent with its customary practice, in calculating Adjusted Net Income (non-GAAP), EOG adds to reported Net Income (GAAP) the total net cash received from settlements of financial commodity derivative contracts during such period. For the twelve months ended December 31, 2024, such amount was $214 million. Adjusted Net Income (Continued) In millions of USD, except share data (in millions) and per share data (Unaudited) FY 2023BeforeTaxIncome Tax ImpactAfterTaxDiluted Earnings per Share Reported Net Income (GAAP) 9,689(2,095)7,59413.00 Adjustments:Gains on Mark-to-Market Financial Commodity Derivative Contracts, Net (818)176(642)(1.09) Net Cash Payments for Settlements of Financial Commodity Derivative Contracts (1) (112)24(88)(0.15) Less: Gains on Asset Dispositions, Net (95)20(75)(0.13) Add: Certain Impairments 42(6)360.06 Adjustments to Net Income (983)214(769)(1.31) Adjusted Net Income (Non-GAAP) 8,706(1,881)6,82511.69 Average Number of Common Shares Basic 581 Diluted 584 (1) Consistent with its customary practice, in calculating Adjusted Net Income (non-GAAP), EOG subtracts from reported Net Income (GAAP) the total net cash paid for settlements of financial commodity derivative contracts during such period. For the twelve months ended December 31, 2023, such amount was $112 million. Net Income per Share In millions of USD, except share data (in millions), per share data, production volume data and per Boe data (Unaudited) 1Q 2025 Net Income per Share (GAAP) - Diluted 2.65 Realized Prices2Q 2025 Composite Average Revenue from Sales of Crude Oil and Condensate, NGLs, and Natural Gas per Boe 39.80 Less: 1Q 2025 Composite Average Revenue from Sales of Crude Oil and Condensate, NGLs, and Natural Gas per Boe (45.88) Subtotal (6.08) Multiplied by: 2Q 2025 Crude Oil Equivalent Volumes (MMBoe) 103.2 Total Change in Revenue (627) Add: Income Tax Benefit (Provision) Imputed (based on 22%) 138 Change in Net Income (489) Change in Diluted Earnings per Share (0.90) Volumes2Q 2025 Crude Oil Equivalent Volumes (MMBoe) 103.2 Less: 1Q 2025 Crude Oil Equivalent Volumes (MMBoe) (98.1) Subtotal 5.1 Multiplied by: 2Q 2025 Composite Average Margin per Boe (GAAP) (Including Total Exploration Costs) (refer to "Revenues, Costs and Margins Per Barrel of Oil Equivalent" schedule below) 14.94 Change in Margin 76 Less: Income Tax Benefit (Provision) Imputed (based on 22%) (17) Change in Net Income 59 Change in Diluted Earnings per Share 0.11 Certain Operating Costs per Boe1Q 2025 Total Cash Operating Costs (GAAP) and Total DD&A per Boe 20.63 Less: 2Q 2025 Total Cash Operating Costs (GAAP) and Total DD&A per Boe (20.25) Subtotal 0.38 Multiplied by: 2Q 2025 Crude Oil Equivalent Volumes (MMBoe) 103.2 Change in Before-Tax Net Income 39 Less: Income Tax Benefit (Provision) Imputed (based on 22%) (9) Change in Net Income 30 Change in Diluted Earnings per Share 0.05 Net Income Per Share (Continued) In millions of USD, except share data (in millions), per share data, production volume data and per Boe data (Unaudited) Gains (Losses) on Mark-to-Market Financial Commodity and Other Derivative Contracts, Net 2Q 2025 Net Gains (Losses) on Mark-to-Market Financial Commodity and Other Derivative Contracts 107 Less: Income Tax Benefit (Provision) (23) After Tax - (a) 84 Less: 1Q 2025 Net Gains (Losses) on Mark-to-Market Financial Commodity and Other Derivative Contracts (191) Less: Income Tax Benefit (Provision) 41 After Tax - (b) (150) Change in Net Income - (a) - (b) 234 Change in Diluted Earnings per Share 0.43 Other (1) 0.12 2Q 2025 Net Income per Share (GAAP) - Diluted 2.46 2Q 2025 Average Number of Common Shares - Diluted 546 (1) Includes gathering, processing and marketing revenue, gains (losses) on asset dispositions (for GAAP earnings per share only), other revenue, exploration costs, dry hole costs, impairments and marketing costs, taxes other than income, other income (expense), interest expense, the impact of changes in the effective income tax rate and the impact of share repurchases on diluted shares. Adjusted Net Income Per Share In millions of USD, except share data (in millions), per share data, production volume data and per Boe data (Unaudited) 1Q 2025 Adjusted Net Income per Share (Non-GAAP) - Diluted 2.87 Realized Prices2Q 2025 Composite Average Revenue from Sales of Crude Oil and Condensate, NGLs, and Natural Gas per Boe 39.80 Less: 1Q 2025 Composite Average Revenue from Sales of Crude Oil and Condensate, NGLs, and Natural Gas per Boe (45.88) Subtotal (6.08) Multiplied by: 2Q 2025 Crude Oil Equivalent Volumes (MMBoe) 103.2 Total Change in Revenue (627) Add: Income Tax Benefit (Provision) Imputed (based on 22%) 138 Change in Net Income (489) Change in Diluted Earnings per Share (0.90) Volumes2Q 2025 Crude Oil Equivalent Volumes (MMBoe) 103.2 Less: 1Q 2025 Crude Oil Equivalent Volumes (MMBoe) (98.1) Subtotal 5.1 Multiplied by: 2Q 2025 Composite Average Margin per Boe (Non-GAAP) (Including Total Exploration Costs) (refer to "Revenues, Costs and Margins Per Barrel of Oil Equivalent" schedule below) 15.21 Change in Margin 78 Add: Income Tax Benefit (Provision) Imputed (based on 22%) (17) Change in Net Income 61 Change in Diluted Earnings per Share 0.11 Certain Operating Costs per Boe1Q 2025 Total Cash Operating Costs (Non-GAAP) and Total DD&A per Boe 20.63 Less: 2Q 2025 Total Cash Operating Costs (Non-GAAP) and Total DD&A per Boe (20.14) Subtotal 0.49 Multiplied by: 2Q 2025 Crude Oil Equivalent Volumes (MMBoe) 103.2 Change in Before-Tax Net Income 51 Add: Income Tax Benefit (Provision) Imputed (based on 22%) (11) Change in Net Income 40 Change in Diluted Earnings per Share 0.07 Adjusted Net Income Per Share (Continued) In millions of USD, except share data (in millions), per share data, production volume data and per Boe data (Unaudited) Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts 2Q 2025 Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts (24) Less: Income Tax Benefit (Provision) 5 After Tax - (a) (19) 1Q 2025 Net Cash Received from (Payments for) Settlements of Financial Commodity Derivative Contracts (38) Less: Income Tax Benefit (Provision) 8 After Tax - (b) (30) Change in Net Income - (a) - (b) 11 Change in Diluted Earnings per Share 0.02 Other (1) 0.15 2Q 2025 Adjusted Net Income per Share (Non-GAAP) 2.32 2Q 2025 Average Number of Common Shares - Diluted 546 (1) Includes gathering, processing and marketing revenue, other revenue, exploration costs, dry hole costs, impairments and marketing costs, taxes other than income, other income (expense), interest expense, the impact of changes in the effective income tax rate and the impact of share repurchases on diluted shares. Cash Flow from Operations and Free Cash Flow In millions of USD (Unaudited) The following tables reconcile Net Cash Provided by Operating Activities (GAAP) to Adjusted Cash Flow from Operations (Non-GAAP). EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust Net Cash Provided by Operating Activities for Changes in Components of Working Capital and Other Assets and Liabilities, Changes in Components of Working Capital Associated with Investing Activities (or Investing and Financing Activities, as applicable) and certain other adjustments to exclude certain non-recurring items and other items as further described below. EOG defines Free Cash Flow (Non-GAAP) for a given period as Adjusted Cash Flow from Operations (Non-GAAP) (see below reconciliation) for such period less the Total Capital Expenditures (Non-GAAP) (see below reconciliation) during such period, as is illustrated below. EOG management uses this information for comparative purposes within the industry. As indicated in the tables below, EOG is (1) in addition to its customary working capital-related adjustments, adjusting Net Cash Provided by Operating Activities (GAAP) to add back certain non-recurring acquisition-related costs incurred during the second quarter 2025 and (2) now presenting such adjusted measure as "Adjusted Cash Flow from Operations (Non-GAAP)" (instead of "Cash Flow from Operations Before Changes in Working Capital (Non-GAAP)" as reported in prior periods); the presentation below with respect to the second quarter 2025 and the prior periods shown has been conformed.202420251st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year1st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year Net Cash Provided by Operating Activities (GAAP) 2,903 2,889 3,588 2,763 12,1432,289 2,032 4,321 Adjustments:Changes in Components of Working Capital and Other Assets and LiabilitiesAccounts Receivable (58) (33) (109) 99 (101)(48) (122) (170) Inventories (117) (75) (30) (37) (259)(76) 45 (31) Accounts Payable 58 (29) 159 (152) 36129 107 236 Accrued Taxes Payable (319) 185 (256) (151) (541)339 321 660 Other Assets 161 (42) (197) 34 (44)43 43 86 Other Liabilities 71 20 (108) (6) (23)96 52 148 Changes in Components of Working Capital Associated with Investing Activities 229 127 (59) 85 38241 8 49 Add:Acquisition-Related Costs (1), Net of Tax — — — — —— 10 10 Adjusted Cash Flow from Operations (Non-GAAP) 2,928 3,042 2,988 2,635 11,5932,813 2,496 5,309 Less:Total Capital Expenditures (Non-GAAP) (2) (1,703) (1,668) (1,497) (1,358) (6,226)(1,484) (1,523) (3,007) Free Cash Flow (Non-GAAP) 1,225 1,374 1,491 1,277 5,3671,329 973 2,302 (1) Consists of Encino acquisition-related G&A costs of $12 million (before tax) for the three months ended June 30, 2025. (2) See below reconciliation of Total Expenditures (GAAP) to Total Capital Expenditures (Non-GAAP):202420251st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year1st Qtr 2nd Qtr 3rd Qtr 4th Qtr Year Total Expenditures (GAAP) 1,952 1,682 1,573 1,446 6,6531,546 1,883 3,429 Less:Asset Retirement Costs (21) 60 (11) (26) 2(13) (14) (27) Non-Cash Acquisition Costs of Unproved Properties (31) (34) (17) (3) (85)(9) (2) (11) Acquisition Costs of Proved Properties (21) (5) — (7) (33)1 (270) (269) Acquisition Costs of Other Property, Plant and Equipment (131) (1) (5) — (137)— — — Exploration Costs (45) (34) (43) (52) (174)(41) (74) (115) Total Capital Expenditures (Non-GAAP) 1,703 1,668 1,497 1,358 6,2261,484 1,523 3,007 Cash Flow from Operations and Free Cash Flow In millions of USD (Unaudited) FY 2023FY 2022 Net Cash Provided by Operating Activities (GAAP) 11,34011,093 Adjustments:Changes in Components of Working Capital and Other Assets and Liabilities Accounts Receivable 38347 Inventories 231534 Accounts Payable 119(90) Accrued Taxes Payable (61)113 Other Assets (39)364 Other Liabilities (184)266 Changes in Components of Working Capital Associated with Investing Activities(295)(375) Adjusted Cash Flow from Operations (Non-GAAP)11,14912,252 Less:Total Capital Expenditures (Non-GAAP) (a) (6,041)(4,607) Free Cash Flow (Non-GAAP) 5,1087,645 (a) See below reconciliation of Total Expenditures (GAAP) to Total Capital Expenditures (Non-GAAP): Total Expenditures (GAAP) 6,8185,610 Less:Asset Retirement Costs (257)(298) Non-Cash Development Drilling (90)— Non-Cash Acquisition Costs of Unproved Properties (99)(127) Acquisition Costs of Proved Properties (16)(419) Acquisition Costs of Other Property, Plant and Equipment (134)— Exploration Costs (181)(159) Total Capital Expenditures (Non-GAAP) 6,0414,607 Net Debt-to-Total Capitalization Ratio In millions of USD, except ratio data (Unaudited)The following tables reconcile Current and Long-Term Debt (GAAP) to Net Debt (Non-GAAP) and Total Capitalization (GAAP) to Total Capitalization (Non-GAAP), as used in the Net Debt-to-Total Capitalization ratio calculation. A portion of the cash is associated with international subsidiaries; tax considerations may impact debt paydown. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize Net Debt and Total Capitalization (Non-GAAP) in their Net Debt-to-Total Capitalization ratio calculation. EOG management uses this information for comparative purposes within the 30,2025March 31,2025December 31,2024September 30,2024June 30,2024 Total Stockholders' Equity - (a) 29,23829,51629,35129,57429,159 Current and Long-Term Debt (GAAP) - (b) 4,2364,7444,7523,7763,784 Less: Cash (5,216)(6,599)(7,092)(6,122)(5,431) Net Debt (Non-GAAP) - (c) (980)(1,855)(2,340)(2,346)(1,647) Total Capitalization (GAAP) - (a) + (b) 33,47434,26034,10333,35032,943 Total Capitalization (Non-GAAP) - (a) + (c) 28,25827,66127,01127,22827,512 Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)] 12.7 %13.8 %13.9 %11.3 %11.5 % Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)] -3.5 %-6.7 %-8.7 %-8.6 %-6.0 % Revenues, Costs and Margins Per Barrel of Oil Equivalent In millions of USD, except Boe and per Boe amounts (Unaudited) EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who review certain components and/or groups of components of revenues, costs and/or margins per barrel of oil equivalent (Boe). Certain of these components are adjusted for non-recurring and certain other items, as further discussed below. EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.2Q 20251Q 20254Q 20243Q 20242Q 2024 Volume - Million Barrels of Oil Equivalent - (a) 103.298.1100.899.095.3 Total Operating Revenues and Other - (b) 5,4785,6695,5855,9656,025 Total Operating Expenses - (c) 3,7313,8103,9933,8763,895 Operating Income - (d) 1,7471,8591,5922,0892,130 Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural Gas Crude Oil and Condensate 2,9743,2933,2613,4883,692 Natural Gas Liquids 534572554524515 Natural Gas 600637494372303 Total Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural Gas - (e) 4,1084,5024,3094,3844,510 Operating CostsLease and Well 396401394392390 Gathering, Processing and Transportation Costs (1) 455440441445423 General and Administrative (GAAP) 186171189167151 Less: Certain Items (see Endnotes 2 & 3 to 2Q 2025 earnings release) (12)——(10)— General and Administrative (Non-GAAP) (3) 174171189157151 Taxes Other Than Income (GAAP) 301341291283337 Add: Severance Tax Refund ———31— Taxes Other Than Income (Non-GAAP) (4) 301341291314337 Interest Expense, Net 5147383136 Less: Acquisition-Related Financing Commitment Costs (6)———— Interest Expense, Net (Non-GAAP) (5) 4547383136 Total Operating Cost (GAAP) (excluding DD&A and Total Exploration Costs) - (f) 1,3891,4001,3531,3181,337 Total Operating Cost (Non-GAAP) (excluding DD&A and Total Exploration Costs) - (g) 1,3711,4001,3531,3391,337 Depreciation, Depletion and Amortization (DD&A) 1,0531,0131,0191,031984 Total Operating Cost (GAAP) (excluding Total Exploration Costs) - (h) 2,4422,4132,3722,3492,321 Total Operating Cost (Non-GAAP) (excluding Total Exploration Costs) - (i) 2,4242,4132,3722,3702,321 Exploration Costs 7441524334 Dry Hole Costs 11348—5 Impairments 39442761581 Total Exploration Costs (GAAP) 12411933658120 Less: Certain Impairments (2) (11)—(254)—(35) Total Exploration Costs (Non-GAAP) 113119825885 Total Operating Cost (GAAP) (including Total Exploration Costs (GAAP)) - (j) 2,5662,5322,7082,4072,441 Total Operating Cost (Non-GAAP) (including Total Exploration Costs (Non- GAAP)) - (k) 2,5372,5322,4542,4282,406 Total Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural Gas less Total Operating Cost (GAAP) (including Total Exploration Costs (GAAP)) 1,5421,9701,6011,9772,069 Total Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural Gas less Total Operating Cost (Non-GAAP) (including Total Exploration Costs (Non-GAAP)) 1,5711,9701,8551,9562,104 Revenues, Costs and Margins Per Barrel of Oil Equivalent (Continued) In millions of USD, except Boe and per Boe amounts (Unaudited) 2Q 20251Q 20254Q 20243Q 20242Q 2024 Per Barrel of Oil Equivalent (Boe) Calculations (GAAP)Composite Average Operating Revenues and Other per Boe - (b) / (a) 53.0857.7955.4160.2563.22 Composite Average Operating Expenses per Boe - (c) / (a) 36.1538.8439.6239.1540.87 Composite Average Operating Income per Boe - (d) / (a) 16.9318.9515.7921.1022.35 Composite Average Revenue from Sales of Crude Oil and Condensate, NGLs, and Natural Gas per Boe - (e) / (a) 39.8045.8842.7444.3147.31 Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) - (f) / (a) 13.4614.2613.4213.3214.03 Composite Average Margin per Boe (excluding DD&A and Total Exploration Costs) - [(e) / (a) - (f) / (a)] 26.3431.6229.3230.9933.28 Total Operating Cost per Boe (excluding Total Exploration Costs) - (h) / (a) 23.6624.5823.5323.7424.35 Composite Average Margin per Boe (excluding Total Exploration Costs) - [(e) / (a) - (h) / (a)] 16.1421.3019.2120.5722.96 Total Operating Cost per Boe (including Total Exploration Costs) - (j) / (a) 24.8625.7926.8624.3325.61 Composite Average Margin per Boe (including Total Exploration Costs) - [(e) / (a) - (j) / (a)] 14.9420.0915.8819.9821.70 Per Barrel of Oil Equivalent (Boe) Calculations (Non-GAAP)Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) - (g) / (a) 13.3014.2613.4213.5314.03 Composite Average Margin per Boe (excluding DD&A and Total Exploration Costs) - [(e) / (a) - (g) / (a)] 26.5031.6229.3230.7833.28 Total Operating Cost per Boe (excluding Total Exploration Costs) - (i) / (a) 23.5024.5823.5323.9524.35 Composite Average Margin per Boe (excluding Total Exploration Costs) - [(e) / (a) - (i) / (a)] 16.3021.3019.2120.3622.96 Total Operating Cost per Boe (including Total Exploration Costs) - (k) / (a) 24.5925.7924.3424.5425.24 Composite Average Margin per Boe (including Total Exploration Costs) - [(e) / (a) - (k) / (a)] 15.2120.0918.4019.7722.07 Revenues, Costs and Margins Per Barrel of Oil Equivalent (Continued) In millions of USD, except Boe and per Boe amounts (Unaudited)202420232022 Volume - Million Barrels of Oil Equivalent - (a) 388.7359.4331.5 Total Operating Revenues and Other - (b) 23,69824,18625,702 Total Operating Expenses - (c) 15,61614,58315,736 Operating Income (Loss) - (d) 8,0829,6039,966 Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural GasCrude Oil and Condensate 13,92113,74816,367 Natural Gas Liquids 2,1061,8842,648 Natural Gas 1,5511,7443,781 Total Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural Gas - (e) 17,57817,37622,796 Operating CostsLease and Well 1,5721,4541,331 Gathering, Processing and Transportation Costs (1) 1,7221,6201,587 General and Administrative (GAAP) 669640570 Less: Severance Tax Consulting Fees (10)—(16) General and Administrative (Non-GAAP) (3) 659640554 Taxes Other Than Income (GAAP) 1,2491,2841,585 Add: Severance Tax Refund 31—115 Taxes Other Than Income (Non-GAAP) (4) 1,2801,2841,700 Interest Expense, Net 138148179 Total Operating Cost (GAAP) (excluding DD&A and Total Exploration Costs) - (f) 5,3505,1465,252 Total Operating Cost (Non-GAAP) (excluding DD&A and Total Exploration Costs) - (g) 5,3715,1465,351 Depreciation, Depletion and Amortization (DD&A) 4,1083,4923,542 Total Operating Cost (GAAP) (excluding Total Exploration Costs) - (h) 9,4588,6388,794 Total Operating Cost (Non-GAAP) (excluding Total Exploration Costs) - (i) 9,4798,6388,893 Exploration Costs 174181159 Dry Hole Costs 14145 Impairments 391202382 Total Exploration Costs (GAAP) 579384586 Less: Certain Impairments (2) (291)(42)(113) Total Exploration Costs (Non-GAAP) 288342473 Total Operating Cost (GAAP) (including Total Exploration Costs (GAAP)) - (j) 10,0379,0229,380 Total Operating Cost (Non-GAAP) (including Total Exploration Costs (Non- GAAP)) - (k) 9,7678,9809,366 Total Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural Gas less Total Operating Cost (GAAP) (including Total Exploration Costs (GAAP)) 7,5418,35413,416 Total Revenues from Sales of Crude Oil and Condensate, NGLs, and Natural Gas less Total Operating Cost (Non-GAAP) (including Total Exploration Costs (Non-GAAP)) 7,8118,39613,430 Revenues, Costs and Margins Per Barrel of Oil Equivalent (Continued) In millions of USD, except Boe and per Boe amounts (Unaudited) 202420232022 Per Barrel of Oil Equivalent (Boe) Calculations (GAAP)Composite Average Operating Revenues and Other per Boe - (b) / (a) 60.9767.3077.53 Composite Average Operating Expenses per Boe - (c) / (a) 40.1840.5847.47 Composite Average Operating Income (Loss) per Boe - (d) / (a) 20.7926.7230.06 Composite Average Revenue from Sales of Crude Oil and Condensate, NGLs, and Natural Gas per Boe - (e) / (a) 45.2248.3468.77 Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) - (f) / (a) 13.7614.3115.84 Composite Average Margin per Boe (excluding DD&A and Total Exploration Costs) - [(e) / (a) - (f) / (a)] 31.4634.0352.93 Total Operating Cost per Boe (excluding Total Exploration Costs) - (h) / (a) 24.3324.0326.53 Composite Average Margin per Boe (excluding Total Exploration Costs) - [(e) / (a) - (h) / (a)] 20.8924.3142.24 Total Operating Cost per Boe (including Total Exploration Costs) - (j) / (a) 25.8225.1028.30 Composite Average Margin per Boe (including Total Exploration Costs) - [(e) / (a) - (j) / (a)] 19.4023.2440.47 Per Barrel of Oil Equivalent (Boe) Calculations (Non-GAAP)Total Operating Cost per Boe (excluding DD&A and Total Exploration Costs) - (g) / (a) 13.8214.3116.14 Composite Average Margin per Boe (excluding DD&A and Total Exploration Costs) - [(e) / (a) - (g) / (a)] 31.4034.0352.63 Total Operating Cost per Boe (excluding Total Exploration Costs) - (i) / (a) 24.3924.0326.83 Composite Average Margin per Boe (excluding Total Exploration Costs) - [(e) / (a) - (i) / (a)] 20.8324.3141.94 Total Operating Cost per Boe (including Total Exploration Costs) - (k) / (a) 25.1324.9828.26 Composite Average Margin per Boe (including Total Exploration Costs) - [(e) / (a) - (k) / (a)] 20.0923.3640.51 (1) Effective January 1, 2024, EOG combined Transportation Costs and Gathering and Processing Costs into one line item titled Gathering, Processing and Transportation Costs. This presentation has been conformed for all periods presented and had no impact on previously reported Net Income. (2) In general, EOG excludes impairments which are (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets). EOG believes excluding these impairments from total exploration costs is appropriate and provides useful information to investors, as such impairments were caused by factors outside of EOG's control (versus, for example, impairments that are due to EOG's proved oil and gas properties not being as productive as it originally estimated). (3) EOG believes excluding the above-referenced items from General and Administrative Costs is appropriate and provides useful information to investors, as EOG views such items as non-recurring. (4) EOG believes excluding the above-referenced items from Taxes Other Than Income is appropriate and provides useful information to investors, as EOG views such items as non-recurring. (5) EOG believes excluding the above-referenced items from Interest Expense, Net is appropriate and provides useful information to investors, as EOG views such items as non-recurring. Additional Key Financial Information (Unaudited)See "Endnotes" below for related discussion and definitions. 2024 Actual2023 Actual2022 Actual Crude Oil and Condensate Volumes (MBod)United States 490.6475.2460.7 Trinidad 0.80.60.6 Total 491.4475.8461.3 Natural Gas Liquids Volumes (MBbld)Total 245.9223.8197.7 Natural Gas Volumes (MMcfd)United States 1,7281,5511,315 Trinidad 220160180 Total 1,9481,7111,495 Crude Oil Equivalent Volumes (MBoed)United States 1,024.5957.5877.5 Trinidad 37.627.330.7 Total 1,062.1984.8908.2 Benchmark PriceOil (WTI) ($/Bbl) 75.7277.6194.23 Natural Gas (HH) ($/Mcf) 2.272.746.64 Crude Oil and Condensate - above (below) WTI1 ($/Bbl)United States 1.701.572.99 Trinidad (11.29)(9.03)(8.07) Natural Gas Liquids - Realizations as % of WTITotal 30.9 %29.7 %39.0 % Natural Gas - above (below) NYMEX Henry Hub2 ($/Mcf)United States (0.28)(0.04)0.63 Natural Gas Realizations3 ($/Mcf)Trinidad 3.653.654.43 Total Expenditures (GAAP) ($MM) 6,6536,8185,610 Capital Expenditures4 (non-GAAP) ($MM) 6,2266,0414,607 Operating Unit Costs ($/Boe)Lease and Well 4.044.054.02 Gathering, Processing and Transportation Costs5 4.434.504.78 General and Administrative (GAAP) 1.721.781.72 General and Administrative (non-GAAP)6 1.701.781.67 Cash Operating Costs (GAAP) 10.1910.3310.52 Cash Operating Costs (non-GAAP)6 10.1710.3310.47 Depreciation, Depletion and Amortization 10.579.7210.69 Expenses ($MM)Exploration and Dry Hole 188182204 Impairment (GAAP) 391202382 Impairment (excluding certain impairments (non-GAAP))7 100160269 Capitalized Interest 453336 Net Interest 138148179 TOTI (% of revenues from sales of crude oil and condensate, NGLs and natural gas)(GAAP) 7.1 %7.4 %7.0 % (non-GAAP)6 7.3 %7.4 %7.5 % Income TaxesEffective Rate 22.1 %21.6 %21.7 % Current Tax Expense ($MM) 1,3481,4152,208 Additional Key Information(Continued)Endnotes 1) EOG bases United States and Trinidad crude oil and condensate price differentials upon the West Texas Intermediate crude oil price at Cushing, Oklahoma, using the simple average of the NYMEX settlement prices for each trading day within the applicable calendar month. 2) EOG bases United States natural gas price differentials upon the natural gas price at Henry Hub, Louisiana, using the NYMEX Last Day Settle price for each of the applicable months. 3) The full-year 2022 realized natural gas price for Trinidad includes a one-time pricing adjustment of $0.76/Mcf for prior-period production following a contract amendment with the National Gas Company of Trinidad and Tobago Limited. 4) Capital Expenditures includes expenditures for Exploration and Development Drilling, Facilities, Leasehold Acquisitions, Capitalized Interest, Dry Hole Costs and Other Property, Plant and Equipment. Capital Expenditures excludes Property Acquisitions, Asset Retirement Costs, Non-Cash Exchanges and Transactions and exploration costs incurred as operating expenses. 5) Effective January 1, 2024, EOG combined Transportation Costs and Gathering and Processing Costs into one line item titled Gathering, Processing and Transportation Costs. This presentation has been conformed for all periods presented and had no impact on previously reported Net Income. 6) Cash Operating Costs consist of LOE, GP&T and G&A. TOTI (% of revenues from sales of crude oil and condensate, NGLs and natural gas) (non-GAAP) and G&A (non-GAAP) for fiscal year 2024 and fiscal year 2022 exclude a state severance tax refund and related consulting fees, respectively, as reflected in the accompanying reconciliation schedules (see "Revenues, Costs and Margins Per Barrel of Oil Equivalent"). The per-Boe impact of such consulting fees on G&A and total Cash Operating Costs for fiscal year 2024 and fiscal year 2022 was $(0.02) and $(0.05), respectively. 7) In general, EOG excludes impairments which are (i) attributable to declines in commodity prices, (ii) related to sales of certain oil and gas properties or (iii) the result of certain other events or decisions (e.g., a periodic review of EOG's oil and gas properties or other assets). EOG believes excluding these impairments from total impairment costs is appropriate and provides useful information to investors, as such impairments were caused by factors outside of EOG's control (versus, for example, impairments that are due to EOG's proved oil and gas properties not being as productive as it originally estimated). View original content: SOURCE EOG Resources, Inc.
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LIVE NATION ENTERTAINMENT REPORTS SECOND QUARTER 2025 RESULTS
LOS ANGELES, Aug. 7, 2025 /PRNewswire/ -- "Global expansion continues to drive touring growth, with fan attendance hitting new highs and ticket buying strong at every price point from VIP to the back row. To meet this momentum, we're expanding our global venue portfolio and investing in the artists who make it all possible. We're continuing to deliver record revenue and concert ticket sales, and with investments focused on high‑growth markets and fan experiences, we're positioned to grow operating income and adjusted operating income by double-digits this year and for years to come." – Michael Rapino, President and CEO GLOBAL FAN DEMAND DRIVES RECORD Q2 RESULTS (vs same period last year) Revenue of $7 billion, up 16% Operating income of $487 million, up 4% Adjusted operating income (AOI) of $798 million, up 11% Record concerts profitability with AOI of $359 million, up 33% Global attendance up 14% to 44 million fans, with stadium attendance tripling Ticketmaster Gross Transaction Value (GTV) increased 7% to $9 billion Strong international growth: Concert fans, Ticketmaster GTV, and Sponsorship sales all up double-digits RECORD CONCERT TICKET SALES AND ONSITE SPENDING (through July vs same period last year) Over 130 million tickets sold for Live Nation concerts, up 6%, led by the strength of our international markets with double-digit attendance increases across stadiums, arenas, and theaters and clubs Strong ticket sales at every price point from premium to budget-friendly seats: Over 40% of global stadium shows sold out 95% of tickets in the first week, up double-digits Over 10% of seats across stadiums, arenas, and amphitheaters in the U.S. priced closer to market value Ticket to Summer promotion sold 1.5 million $30 lawn seats, consistent with historical levels Continued growth in onsite spending across all venue types, including concession spending at large amphitheaters up double-digits KEY METRICS POINT TO ANOTHER RECORD YEAR (vs same period last year) Q2 deferred revenue highlights accelerating momentum Concerts event-related deferred revenue $5.1 billion, up 25% All-time high Ticketmaster deferred revenue $317 million, up 22% Venue Nation expected to host approximately 70 million fans this year, up double-digits 95% of expected 2025 sponsorship committed, up double-digits CONCERTS DELIVERS Q2 RECORD FINANCIAL RESULTS AND ATTENDANCE (vs 2Q24) Highest-ever Q2 revenue of $6 billion, up 19% Record Q2 AOI of $359 million, up 33% Margin of 6%, up 60 basis points Global attendance grew 14% to 44 million fans Global stadiums tripled in fan count from last year International arena fan count up 20% Overall fan count at international markets up over 30%, driven by strength across Europe, Asia-Pacific and Latin America GLOBAL GROWTH POWERS MOMENTUM THROUGH THE REMAINDER OF THE YEAR Nearly all large venue shows booked for the rest of 2025 Double-digit international fan growth expected in 2H Full-year AOI margins on track to be consistent with last year Investing $15 billion in artist events globally in 2025, making Live Nation the largest financial supporter of the artist community VENUE NATION HOSTING MORE SHOWS AND FANS GLOBALLY Further expanded our venue portfolio, opening four amphitheaters across the U.S. and adding one stadium in Canada year-to-date. We expect to bring additional venues online in 2H, with key projects underway in Mexico, Colombia, and Canada Our venue development pipeline continues to grow, expecting ten new large venues to open next year – each with fan capacity of 3,000 and above – across the U.S. and international markets Collectively, these venues create incremental capacity for six million fans on a run-rate basis Venue capital investments for new builds and refurbishments continue to deliver 20%+ returns New amphitheaters are delivering strong results, with food and beverage sales tracking double-digits higher compared to our historical portfolio, while also selling out premium seating Based on our current assessment, tariffs are expected to have minimal impact on venue investment costs, festival supply chain, and other costs CONCERTS AND INTERNATIONAL ACTIVITY DRIVES TICKETMASTER RESULTS (vs 2Q24) Revenue of $743 million, up 2% AOI of $290 million, consistent with last year Record Q2 total reported GTV of $9 billion, up 7% Secondary GTV down mid-single digits due to increased market-based pricing in concerts and sports along with several lower-performing sporting events Over 83 million fee-bearing tickets sold, up 4% International ticket volume up double-digits Concerts ticket volume up high-single digits while sports and other content continued to trail 2024 levels TICKETMASTER POSITIONED FOR GROWTH IN SECOND HALF OF 2025 (through July vs same period last year) Q2 record deferred revenue of $317 million, up 22%, driven by Live Nation concerts activity 17 million net new enterprise tickets signed, up 10%, with approximately 70% of the growth from international markets On track to grow AOI double-digits in 2H Full-year AOI margin expected to be consistent with prior years GLOBAL REACH AND SCALE CONTINUES TO ATTRACT BRAND PARTNERS Revenue of $341 million, up 9% AOI of $228 million, up 2% Expanding our portfolio of brand partners through new agreements with major consumer brands including Kraft Heinz, Airbnb, and Samsung; as well as a ticket access agreement with United Airlines Global venue portfolio expanding its name-in-title sponsorships, including TD Coliseum at Hamilton and Veikkaus Arena at Helsinki BRANDS CONTINUE TO SEE STRATEGIC VALUE FROM ENGAGING WITH CONCERT FANS (through July vs same period last year) 95% of revenue committed for 2025, up double-digits On track to deliver double-digit increase in AOI for the full year, with notable strength in Q4 Full-year AOI margin expected to be consistent with prior years STRONG BALANCE SHEET TO SUPPORT STRATEGIC VENUE EXPANSION Year-to-date net cash provided by operating activities of $1.5 billion and free cash flow—adjusted of $654 million, up 5%, and on track to grow both of these metrics by double-digits for the full year relative to last year Year-to-date capital expenditures of $420 million; 2025 full year capital expenditures estimated to be $900 million to $1 billion $700 to $800 million of total capex is related to venue expansion and enhancement plans, for which the cash outlay will be reduced by approximately $200 million from funding by joint-venture partners, sponsorship agreements, and other sources Maintenance capex spend remains consistent with historical levels Over 90% of our debt is at fixed rates with a weighted average cost of debt of approximately 4.4%, with no remaining debt maturities this year FINANCIAL DETAILS FROM THE ADDITIONAL 24% PURCHASE OF OCESA The transaction will increase our ownership to 75% and is expected to close in August Largely as a result of OCESA's continued growth and the amended purchase agreement, total accretion for Q3 is expected to be $250 million and then fall to $35 million in Q4 Full-year non-controlling interest expense is expected to increase in line with our AOI growth These estimates are based on current projections for OCESA performance, current FX rates, and assume all other joint-ventures performance in line with current forecasts OTHER FINANCIAL INFORMATION The cumulative effect on Q2 net income of accretion, higher taxes, and foreign exchange was $185 million higher cost compared to last year, impacting EPS Based on current projected rates, foreign exchange is not expected to materially impact 2H financials Full year depreciation and amortization expected to increase by approximately $75 million compared to last year Our full-year P&L tax expense is expected to be 15-20% of our AOI. Carryforward operating losses will continue to reduce our U.S. cash taxes, resulting in global cash tax payments that are projected to be 20-25% lower than our P&L expense 2025 share count not expected to change materially from 2024 Compare Our Operating Results To Past Quarters In The Trended Results Grid: The company will webcast a teleconference today, August 7, 2025, at 2:00 p.m. Pacific Time to discuss its financial performance, operational matters and potentially other material developments. Interested parties should visit the "News / Events" section of the company's website at to listen to the webcast. Supplemental statistical and financial information to be provided on the call, if any, will be posted to the "Financial Info" section of the website. A replay of the webcast will also be available on the Live Nation website. The link to the 2Q25 Trended Results Grid is provided above for convenience and such grid is not a part of, or incorporated into, this press release or any SEC filings that include this press release. Notice Regarding Financial Statements The company has provided certain financial statements at the end of this press release for reference. These financial statements should be read in conjunction with the full financial statements, and the notes thereto, set forth in the company's Quarterly Report on Form 10-Q for the quarter ended June 30, 2025 to be filed with the Securities and Exchange Commission today and available on the SEC's website at About Live Nation Entertainment: Live Nation Entertainment, Inc. (NYSE: LYV) is the world's leading live entertainment company comprised of global market leaders: Ticketmaster, Live Nation Concerts, and Live Nation Media & Sponsorship. For additional information, visit FINANCIAL HIGHLIGHTS – SECOND QUARTER (unaudited; $ in millions) Q2 2025 ReportedQ2 2024 ReportedChangeQ2 2025 Currency ImpactsQ2 2025 at Constant CurrencyChange at Constant Currency RevenueConcerts $ 5,946.4$ 4,987.019 %$ (67.3)$ 5,879.118 % Ticketing 742.7730.72 %3.0745.72 % Sponsorship & Advertising 340.6312.29 %5.5346.111 % Other and Eliminations (23.1)(6.5)*0.2(22.9)*$ 7,006.6$ 6,023.416 %$ (58.6)$ 6,948.015 % Consolidated Operating Income $ 486.7$ 465.84 %$ (4.3)$ 482.44 % Adjusted Operating Income (Loss) Concerts $ 358.7$ 270.733 %$ (9.1)$ 349.629 % Ticketing 290.1292.5(1) %3.6293.7* Sponsorship & Advertising 227.6222.62 %1.7229.33 % Other and Eliminations (6.8)(8.2)*0.0(6.8)* Corporate (71.2)(61.4)(16) %0.1(71.1)(16) %$ 798.4$ 716.211 %$ (3.7)$ 794.711 %* Percentages are not meaningful FINANCIAL HIGHLIGHTS – SIX MONTHS (unaudited; $ in millions) 6 Months 2025 Reported6 Months 2024 ReportedChange6 Months 2025 Currency Impacts6 Months 2025 Constant CurrencyChange at Constant Currency RevenueConcerts $ 8,430.5$ 7,866.47 %$ 17.7$ 8,448.27 % Ticketing 1,437.41,453.9(1) %22.61,460.0* Sponsorship & Advertising 556.6523.56 %18.8575.410 % Other and Eliminations (35.7)(20.9)*0.0(35.7)*$ 10,388.8$ 9,822.96 %$ 59.1$ 10,447.96 % Consolidated Operating Income $ 601.4$ 424.442 %$ 10.5$ 611.944 % Adjusted Operating Income (Loss) Concerts $ 365.3$ 268.936 %$ (9.6)$ 355.732 % Ticketing 543.2576.6(6) %15.6558.8(3) % Sponsorship & Advertising 363.6352.63 %9.9373.56 % Other and Eliminations (12.7)(15.4)*0.0(12.7)* Corporate (119.9)(104.0)(15) %0.2(119.7)(15) %$ 1,139.5$ 1,078.76 %$ 16.1$ 1,155.67 %* Percentages are not meaningful Reconciliation of Operating Income to Adjusted Operating Income (unaudited; $ in millions) Q2 2025 Q2 20246 Months 2025 6 Months 2024 Operating Income $ 486.7 $ 465.8$ 601.4 $ 424.4 Acquisition expenses 79.2 (30.0)109.0 0.6 Amortization of non-recoupable ticketing contract advances 20.7 21.245.4 45.2 Depreciation and amortization 159.0 137.7308.5 270.3 Gain on sale of operating assets (0.9) (0.8)(3.1) (1.4) Astroworld estimated loss contingencies (7.8) 94.0(7.8) 279.9 Stock-based compensation expense 61.5 28.386.1 59.7 Adjusted Operating Income $ 798.4 $ 716.2$ 1,139.5 $ 1,078.7 Reconciliations of Certain Non-GAAP Measures to Their Most Directly Comparable GAAP Measures (unaudited; $ in millions)Reconciliation of Free Cash Flow — Adjusted to Net Cash Provided by Operating Activities ($ in millions) Q2 2025Q2 2024 Net cash provided by operating activities $ 223.4$ 412.1 Changes in operating assets and liabilities (working capital) 387.892.7 Changes in accrued liabilities for Astroworld estimated loss contingencies (7.8)94.0 Free cash flow from earnings $ 603.4$ 598.8 Less: Maintenance capital expenditures (34.2)(27.1) Distributions to noncontrolling interests (131.1)(115.7) Free cash flow — adjusted $ 438.1$ 456.0 Net cash used in investing activities $ (275.0)$ (263.7) Net cash used in financing activities $ (325.3)$ (164.6) Reconciliation of Free Cash Flow — Adjusted to Net Cash Provided by Operating Activities($ in millions) 6 Months 20256 Months 2024 Net cash provided by operating activities $ 1,544.7$ 1,401.0 Changes in operating assets and liabilities (working capital) (668.8)(835.2) Changes in accrued liabilities for Astroworld estimated loss contingencies (7.8)279.9 Free cash flow from earnings $ 868.1$ 845.7 Less: Maintenance capital expenditures (49.1)(49.6) Distributions to noncontrolling interests (164.8)(171.9) Free cash flow — adjusted $ 654.2$ 624.2 Net cash used in investing activities $ (492.4)$ (434.4) Net cash used in financing activities $ (498.5)$ (643.0) Reconciliation of Free Cash to Cash and Cash Equivalents($ in millions) June 30,2025 Cash and cash equivalents $ 7,057.0 Short-term investments 57.6 Client cash (1,703.2) Deferred revenue — event-related (5,140.3) Accrued artist fees (339.0) Collections on behalf of others (123.0) Prepaid expenses — event-related 1,290.5 Free cash $ 1,099.6Forward-Looking Statements, Non-GAAP Financial Measures and Reconciliations: Certain statements in this press release, including the Supplemental Information that follows, constitute "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. Such forward-looking statements include, but are not limited to statements regarding the company's positioning to grow operating income and adjusted operating income by double digit in 2025 and for years to come; key metrics pointing to another record year; expected Venue Nation fans for 2025; the level of expected 2025 sponsorship; the expectation that global growth will power momentum in the company's Concerts segment through the remainder of 2025, with double-digit international fan growth expected in the second half of the year; the company's expectations for full-year 2025 adjusted operating income margins in its Concerts segment; the anticipated level of investment in artist events globally for 2025; expectations regarding key projects and additional venues planned to come online in the second half of 2025 in the company's global portfolio of operated venues, the company's venue development pipeline for 2026 in the U.S. and internationally, and the anticipated incremental fans from these projects; the anticipated minimal impact of tariffs on venue investment costs, festival supply chain, and other costs; Ticketmaster's positioning for growth in the second half of 2025; anticipated adjusted operating income growth in the second half of 2025 for Ticketmaster; expectations for Ticketmaster's full-year adjusted operating income margin; the Sponsorship & Advertising segment's anticipated increase in adjusted operating income for 2025, with expected strength in the fourth quarter; full-year 2025 adjusted operating income and adjusted operating income margin expectations for the Sponsorship & Advertising segment; expectations for full-year 2025 net cash provided by operating activities and free cash flow—adjusted growth; estimated capital expenditures for 2025, including those related to venue expansion and enhancement plans; the anticipated closing timeline and financial impact of the company's additional purchase of OCESA, including expected total accretion levels for the third and fourth quarters of 2025, and anticipated full-year non-controlling interest expense for 2025; the company's expectation that foreign exchange rates will not materially impact financials in the second half of 2025; the expected level of depreciation and amortization for full-year 2025; expected P&L tax expense for 2025 and global cash tax payments; and expectations for 2025 share count. Live Nation wishes to caution you that there are some known and unknown factors that could cause actual results to differ materially from any future results, performance or achievements expressed or implied by such forward-looking statements, including but not limited to operational challenges in achieving strategic objectives and executing on the company's plans, the risk that the company's markets do not evolve as anticipated, the potential impact of any economic slowdown and operational challenges associated with selling tickets and staging events. Live Nation refers you to the documents it files from time to time with the U.S. Securities and Exchange Commission, or SEC, specifically the section titled "Item 1A. Risk Factors" of the company's most recent Annual Report filed on Form 10-K, and Quarterly Reports on Form 10-Q and its Current Reports on Form 8-K, which contain and identify other important factors that could cause actual results to differ materially from those contained in the company's projections or forward-looking statements. You are cautioned not to place undue reliance on these forward-looking statements which speak only as of the date on which they are made. All subsequent written and oral forward-looking statements by or concerning Live Nation are expressly qualified in their entirety by the cautionary statements above. Live Nation does not undertake any obligation to publicly update or revise any forward-looking statements because of new information, future events or otherwise. This press release contains certain non-GAAP financial measures as defined by SEC Regulation G. A reconciliation of each such measure to its most directly comparable GAAP financial measure, together with an explanation of why management believes that these non-GAAP financial measures provide useful information to investors, is provided herein. Adjusted Operating Income (Loss), or AOI, is a non-GAAP financial measure that we define as operating income (loss) before certain acquisition expenses (including ongoing legal costs stemming from the Ticketmaster merger, changes in the fair value of accrued acquisition-related contingent consideration obligations, and acquisition-related severance and compensation), amortization of non-recoupable ticketing contract advances, depreciation and amortization (including goodwill impairment), loss (gain) on disposal of operating assets, and stock-based compensation expense. We also exclude from AOI the impact of estimated or realized liabilities for settlements or damages arising out of the Astroworld matter that exceed our estimated insurance recovery, due to the significant and non-recurring nature of the matter. Ongoing legal costs associated with defense of these claims, such as attorney fees, are not excluded from AOI. We use AOI to evaluate the performance of our operating segments. We believe that information about AOI assists investors by allowing them to evaluate changes in the operating results of our portfolio of businesses separate from non-operational factors that affect net income (loss), thus providing insights into both operations and the other factors that affect reported results. AOI is not calculated or presented in accordance with GAAP. A limitation of the use of AOI as a performance measure is that it does not reflect the periodic costs of certain amortizing assets used in generating revenue in our business. Accordingly, AOI should be considered in addition to, and not as a substitute for, operating income (loss), net income (loss), and other measures of financial performance reported in accordance with GAAP. Furthermore, this measure may vary among other companies; thus, AOI as presented herein may not be comparable to similarly titled measures of other companies. AOI margin is a non-GAAP financial measure that we calculate by dividing AOI by revenue. We use AOI margin to evaluate the performance of our operating segments. We believe that information about AOI margin assists investors by allowing them to evaluate changes in the operating results of our portfolio of businesses separate from non-operational factors that affect net income (loss), thus providing insights into both operations and the other factors that affect reported results. AOI margin is not calculated or presented in accordance with GAAP. A limitation of the use of AOI margin as a performance measure is that it does not reflect the periodic costs of certain amortizing assets used in generating revenue in our business. Accordingly, AOI margin should be considered in addition to, and not as a substitute for, operating income (loss) margin, and other measures of financial performance reported in accordance with GAAP. Furthermore, this measure may vary among other companies; thus, AOI margin as presented herein may not be comparable to similarly titled measures of other companies. Constant Currency is a non-GAAP financial measure when applied to a GAAP financial measure. We calculate currency impacts as the difference between current period activity translated using the current period's currency exchange rates and the comparable prior period's currency exchange rates. We present constant currency information to provide a framework for assessing how our underlying businesses performed excluding the effect of foreign currency rate fluctuations. Free Cash Flow—Adjusted, or FCF, is a non-GAAP financial measure that we define as net cash provided by (used in) operating activities less changes in operating assets and liabilities, less maintenance capital expenditures, less distributions to noncontrolling interest partners. We use FCF among other measures, to evaluate the ability of operations to generate cash that is available for purposes other than maintenance capital expenditures. We believe that information about FCF provides investors with an important perspective on the cash available to service debt, make acquisitions, and for revenue generating capital expenditures. FCF is not calculated or presented in accordance with GAAP. A limitation of the use of FCF as a performance measure is that it does not necessarily represent funds available for operations and is not necessarily a measure of our ability to fund our cash needs. Accordingly, FCF should be considered in addition to, and not as a substitute for, net cash provided by (used in) operating activities and other measures of financial performance reported in accordance with GAAP. Furthermore, this measure may vary among other companies; thus, FCF as presented herein may not be comparable to similarly titled measures of other companies. Free Cash is a non-GAAP financial measure that we define as cash and cash equivalents less ticketing-related client funds, less event-related deferred revenue, less accrued expenses due to artists and cash collected on behalf of others, plus event-related prepaids. We use free cash as a proxy for how much cash we have available to, among other things, optionally repay debt balances, make acquisitions and fund revenue generating capital expenditures. Free cash is not calculated or presented in accordance with GAAP. A limitation of the use of free cash as a performance measure is that it does not necessarily represent funds available from operations and it is not necessarily a measure of our ability to fund our cash needs. Accordingly, free cash should be considered in addition to, and not as a substitute for, cash and cash equivalents and other measures of financial performance reported in accordance with GAAP. Furthermore, this measure may vary among other companies; thus, free cash as presented herein may not be comparable to similarly titled measures of other companies. LIVE NATION ENTERTAINMENT, INC. CONSOLIDATED BALANCE SHEETS (unaudited) June 30,2025December 31,2024(in thousands) ASSETSCurrent assets Cash and cash equivalents $ 7,056,975$ 6,095,424 Accounts receivable, less allowance of $81,087 and $72,663, respectively 2,464,8291,747,316 Prepaid expenses 1,911,7061,247,184 Restricted cash 12,62510,685 Other current assets 377,016189,528 Total current assets 11,823,1519,290,137 Property, plant and equipment, net 2,949,2932,441,872 Operating lease assets 1,738,2181,618,033 Intangible assets Definite-lived intangible assets, net 1,091,697985,812 Indefinite-lived intangible assets, net 369,073380,558 Goodwill 2,820,9182,620,911 Long-term advances 626,920520,482 Other long-term assets 1,731,0631,780,966 Total assets $ 23,150,333$ 19,638,771 LIABILITIES AND EQUITYCurrent liabilities Accounts payable, client accounts $ 2,116,846$ 1,859,678 Accounts payable 404,877242,978 Accrued expenses 3,285,8663,057,334 Deferred revenue 5,910,0683,721,092 Current portion of long-term debt, net 1,485,353260,901 Current portion of operating lease liabilities 158,577153,406 Other current liabilities 96,98562,890 Total current liabilities 13,458,5729,358,279 Long-term debt, net 4,990,9956,177,168 Long-term operating lease liabilities 1,784,7191,680,266 Other long-term liabilities 610,465477,763 Commitments and contingent liabilitiesRedeemable noncontrolling interests 1,377,6651,126,302 Stockholders' equityCommon stock 2,3242,313 Additional paid-in capital 1,788,3932,059,746 Accumulated deficit (1,271,336)(1,546,819) Cost of shares held in treasury (6,865)(6,865) Accumulated other comprehensive loss (152,446)(335,112) Total Live Nation stockholders' equity 360,070173,263 Noncontrolling interests 567,847645,730 Total equity 927,917818,993 Total liabilities and equity $ 23,150,333$ 19,638,771 LIVE NATION ENTERTAINMENT, INC. CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited) Three Months Ended June 30,Six Months Ended June 30,2025202420252024(in thousands except share and per share data) Revenue $ 7,006,641$ 6,023,416$ 10,388,758$ 9,822,945 Operating expenses:Direct operating expenses 5,210,7564,408,2097,465,6937,059,549 Selling, general and administrative expenses 1,003,344926,2221,782,2661,907,781 Depreciation and amortization 159,025137,729308,480270,323 Gain on disposal of operating assets (856)(779)(3,058)(1,430) Corporate expenses 147,71986,216233,955162,293 Operating income 486,653465,819601,422424,429 Interest expense 72,04879,970152,391160,661 Interest income (37,893)(44,425)(71,954)(87,682) Equity in earnings of nonconsolidated affiliates (4,268)(5,376)(4,747)(5,460) Other expense (income), net 36,380(20,742)39,333(97,796) Income before income taxes 420,386456,392486,399454,706 Income tax expense 117,64580,164137,356121,183 Net income 302,741376,228349,043333,523 Net income attributable to noncontrolling interests 59,33078,25882,42990,028 Net income attributable to common stockholders of Live Nation $ 243,411$ 297,970$ 266,614$ 243,495 Basic net income per common share available to common stockholders of Live Nation $ 0.41$ 1.05$ 0.09$ 0.48 Diluted net income per common share available to common stockholders of Live Nation $ 0.41$ 1.03$ 0.09$ 0.48 Weighted average common shares outstanding:Basic 231,845,412229,921,527231,534,852229,696,356 Diluted 234,417,428245,002,995234,658,608232,024,314 Reconciliation to net income available to common stockholders of Live Nation: Net income attributable to common stockholders of Live Nation $ 243,411$ 297,970$ 266,614$ 243,495 Accretion of redeemable noncontrolling interests (147,801)(57,325)(245,895)(132,435) Net income available to common stockholders of Live Nation—basic $ 95,610$ 240,645$ 20,719$ 111,060 Convertible debt interest, net of tax —10,790—— Net income available to common stockholders of Live Nation—diluted $ 95,610$ 251,435$ 20,719$ 111,060 LIVE NATION ENTERTAINMENT, INC. CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) Six Months Ended June 30,20252024(in thousands) CASH FLOWS FROM OPERATING ACTIVITIESNet income $ 349,043$ 333,523 Reconciling items:Depreciation 183,804146,168 Amortization of definite-lived intangibles 124,676124,155 Amortization of non-recoupable ticketing contract advances 45,44345,241 Deferred income taxes 25,129(6,078) Amortization of debt issuance costs and discounts 8,1317,881 Stock-based compensation expense 86,09759,738 Unrealized changes in fair value of contingent consideration 9,304(28,573) Equity in losses of nonconsolidated affiliates, net of distributions 8,7745,671 Provision for uncollectible accounts receivable 13,539(9,806) Loss (Gain) on mark-to-market of investments in nonconsolidated affiliates and crypto assets 133(100,153) Loss (Gain) on forward currency exchange contracts 31,584(8,019) Other, net (9,730)(3,953) Changes in operating assets and liabilities, net of effects of acquisitions and dispositions:Increase in accounts receivable (622,765)(465,797) Increase in prepaid expenses and other assets (822,523)(646,147) Increase in accounts payable, accrued expenses and other liabilities 225,791430,886 Increase in deferred revenue 1,888,2921,516,217 Net cash provided by operating activities 1,544,7221,400,954 CASH FLOWS FROM INVESTING ACTIVITIESAdvances of notes receivable (19,156)(75,973) Collections of notes receivable 17,78421,290 Investments made in nonconsolidated affiliates (14,492)(30,593) Purchases of property, plant and equipment (434,207)(333,689) Cash paid for acquisition of right-of-use assets (20,800)— Cash paid for acquisitions, net of cash acquired (50,090)(17,579) Proceeds from sale of intangible assets 20,040— Other, net 8,4952,139 Net cash used in investing activities (492,426)(434,405) CASH FLOWS FROM FINANCING ACTIVITIESProceeds from long-term debt, net of debt issuance costs 62,764886 Payments on long-term debt including extinguishment costs (103,625)(377,132) Contributions from noncontrolling interests 11,26428 Distributions to noncontrolling interests (164,819)(171,908) Purchases of noncontrolling interests, net (206,112)(47,980) Proceeds from exercise of stock options 3,44312,819 Taxes paid for net share settlement of equity awards (86,585)(38,551) Payments for deferred and contingent consideration (14,399)(20,390) Other, net (383)(748) Net cash used in financing activities (498,452)(642,976) Effect of exchange rate changes on cash, cash equivalents and restricted cash 409,647(152,989) Net increase in cash, cash equivalents and restricted cash 963,491170,584 Cash, cash equivalents and restricted cash at beginning of period 6,106,1096,238,956 Cash, cash equivalents and restricted cash at end of period $ 7,069,600$ 6,409,540 View original content to download multimedia: SOURCE Live Nation Entertainment Sign in to access your portfolio
