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003Q 2026 Earnings Presentation 2026 THIRD QUARTER EARNINGS ERIC M. HAMBLY PRESIDENT AND CHIEF EXECUTIVE OFFICER NOVEMBER 5, 2026 CONFERENCE CALL AND WEBCAST
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113Q 2026 Earnings Presentation CAUTIONARY ST A TEMENT Cautionary Note to US Investors – The United States Securities and Exchange Commission (SEC) requires oil and natural gas companies, in their filings with the SEC, to disclose proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. We may use certain terms in this presentation, such as “resource”, “gross resource”, “recoverable resource”, “net risked PMEAN resource”, “recoverable oil”, “resource base”, “EUR” or “estimated ultimate recovery” and similar terms that the SEC’s rules prohibit us from including in filings with the SEC. The SEC permits the optional disclosure of probable and possible reserves in our filings with the SEC. Investors are urged to consider closely the disclosures and risk factors in our most recent Annual Report on Form 10-K filed with the SEC and any subsequent Quarterly Report on Form 10-Q or Current Report on Form 8-K that we file, available from the SEC’s website. This presentation contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements are generally identified through the inclusion of words such as “aim”, “anticipate”, “believe”, “drive”, “estimate”, “expect”, “forecast”, “future”, “goal”, “guidance”, “intend”, “may”, “objective”, “outlook”, “plan”, “position”, “potential”, “project”, “seek”, “should”, “strategy”, “target”, “will” or variations of such words and other similar expressions. These statements, which express management’s current views concerning future events, results and plans, are subject to inherent risks, uncertainties and assumptions (many of which are beyond our control) and are not guarantees of performance. In particular, statements, express or implied, concerning the Company’s future operating results or activities and returns or the Company's ability and intent to replace or increase reserves, increase production, generate returns and rates of return, replace or increase drilling locations, reduce or otherwise control operating costs and expenditures, generate cash flows, pay down or refinance indebtedness, achieve, reach or otherwise meet initiatives, plans, goals, ambitions or targets with respect to emissions, safety matters or other environmental, social and governance matters, make capital expenditures, pay and/or increase dividends or make share repurchases and other capital allocation decisions are forward-looking statements. Factors that could cause one or more of these future events, results or plans not to occur as implied by any forward-looking statement, which consequently could cause actual results or activities to differ materially from the expectations expressed or implied by such forward-looking statements, include, but are not limited to: macro conditions in the oil and natural gas industry, including supply and demand levels, actions taken by major oil exporters and the resulting impacts on commodity prices; geopolitical concerns (including the ongoing conflict in the Middle East involving Iran); increased volatility or deterioration in the success rate of our exploration programs or in our ability to maintain production rates and replace reserves; reduced customer demand for our products due to environmental, regulatory, technological or other reasons; adverse foreign exchange movements; political and regulatory instability in the markets where we do business; the impact on our operations or markets of health pandemics and related government responses; natural hazards impacting our operations or markets; any other deterioration in our business, markets or prospects; cyber attacks and other cybersecurity risks; any failure to obtain necessary regulatory approvals; the impact of current and future laws, rulings and governmental regulations; any inability to service or refinance our outstanding debt or to access debt markets at acceptable prices; or adverse developments in the U.S. or global capital markets, credit markets, banking system or economies in general, including inflation, trade policies, tariffs and other trade restrictions. For further discussion of factors that could cause one or more of these future events or results not to occur as implied by any forward-looking statement, see “Risk Factors” in our most recent Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission (SEC) and any subsequent Quarterly Report on Form 10-Q or Current Report on Form 8-K that we file, available from the SEC’s website and from Murphy Oil Corporation’s website at http://ir.murphyoilcorp.com. Investors and others should note that we may announce material information using SEC filings, press releases, public conference calls, webcasts and the investors page of our website. We may use these channels to distribute material information about the Company; therefore, we encourage investors, the media, business partners and others interested in the Company to review the information we post on our website. The information on our website is not part of, and is not incorporated into, this presentation. Each forward-looking statement contained in this presentation speaks only as of the date of this presentation. Except as required by applicable law, Murphy Oil Corporation undertakes no duty to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. Non-GAAP Financial Measures – This presentation contains certain non-GAAP financial measures that management believes are useful tools for internal use and the investment community in evaluating Murphy Oil Corporation’s overall financial performance. These non-GAAP financial measures are broadly used to value and compare companies in the crude oil and natural gas industry. Not all companies define these measures in the same way. In addition, these non-GAAP financial measures are not a substitute for financial measures prepared in accordance with US generally accepted accounting principles (GAAP) and should therefore be considered only as supplemental to such GAAP financial measures. Definitions and reconciliations of these measures are included in the appendix.
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223Q 2026 Earnings Presentation Eagle Ford Shale Gulf of America Offshore Canada Production Exploration Development Onshore Canada Côte d’Ivoire Vietnam Morocco Mauritania 2 An independent exploration and production company with a diverse portfolio that provides operational flexibility and exploration upside 1 Excluding noncontrolling interest. Proved reserves are based on YE 2025 third-party audited volumes using SEC pricing Strategic Capital Allocation Balanced Risk and Growth History of Strong Execution US Onshore Offshore Canada Onshore 23% 33% 44% 3Q 2026 Production1 186 MBOEPD 24% 20% 56% 2025 Proved Reserves1 715 MMBOE Complementary Cash Flow and Growth Engines Conventional Offshore Cash Generation and Stability Unconventional North America Operational Flexibility International Exploration Growth Opportunity MURPHY A T A GLANCE 3Q 2026 Earnings Presentation
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333Q 2026 Earnings Presentation UNIQUE INVESTMENT PROPOSITION 3 Multi-basin Portfolio with Operational Financial Discipline Driving Shareholder Returns Industry Leading Track Record of Transformative Exploration Upside Decades of High-quality Inventory Maintaining Strong Proved Reserve Life 3Q 2026 Earnings Presentation Note: Production volumes and financial amounts exclude noncontrolling interest 1 As of September 30, 2026 DISCOVERY TO FIRST OIL >700 MMBOE Proved reserves $4.6 BN1 Cumulative shareholder returns since 2013 FLEXIBILITY to respond to macro cycles 50 YEARS of onshore inventory 1 BBOE + unrisked gross resource potential
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443Q 2026 Earnings Presentation STRONG BALANCE SHEET AND SHAREHOLDER RETURNS Bond Maturity Profile $ MM $0 $200 $400 $600 2026 2027 2028 2029 2030 2031 2032 2033 2034 2042 Long-Term Debt Profile Total Bonds Outstanding $1.6 BN Weighted Avg Fixed Coupon 6.3% Weighted Avg Years to Maturity 8.4 years 3Q Financial Highlights 1 Comprised of $2.0 billion undrawn under the senior unsecured credit facility and $500 MM in cash, inclusive of noncontrolli ng interest 2 See Appendix for reconciliation of non-GAAP measures and supplemental information Cumulative Shareholder Returns Since 2013 $ BN $0.0 $1.0 $2.0 $3.0 $4.0 $5.0 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 YTD 2026 Cumulative Dividends Cumulative Repurchases Liquidity of $2.5 billion1 Maintaining low leverage of 0.9x 2 Free Cash Flow of $48 MM2 Returned $50 MM to shareholders $550 MM remaining Board authorized share repurchase program 2 Minimum of 50% of adjusted FCF2 allocated to shareholder returns and up to 50% to the balance sheet
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553Q 2026 Earnings Presentation OPERA TIONS AND EXPLORA TION UPDA TE
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663Q 2026 Earnings Presentation ADVANCING STRA TEGIC PRIORITIES IN 3Q 2026 63Q 2026 Earnings Presentation Expanding Our Exploration P ortfolio Delivering Long-T erm Shareholder Value Returned $50 MM to shareholders through dividends Advanced Bubale appraisal with success at Bubale West-1X Finalizing appraisal plans for 2027 and 2028 Discovered oil at Lac Da Trang (White Camel) North-1X Potential future tie back to Lac Da Vang Commenced production from Chinook #8 development well with peak gross production of 15 MBOEPD Developing Our Resources Efficiently Reduced YoY well cost per lateral foot by 26% in 2026 while delivering top-tier performance Gulf of America Eagle Ford Shale Côte d’Ivoire Vietnam Achieved first oil with initial production in line with expectations Less than 3 years from sanction to first oil Lac Da Vang (Golden Camel)
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773Q 2026 Earnings Presentation 3Q KEY METRICS 1 Development CAPEX includes $11 MM of corporate CAPEX 2 See Appendix for reconciliation of non-GAAP measures and slide notes providing definitions and other information Note: Production volumes and financial amounts exclude noncontrolling interest; prices exclude hedges and are before transportation, gathering, and processing; figures may not add due to rounding 44 MBOEPD 61 MBOEPD 82 MBOEPD 45% Oil | 7% NGLs | 48% Natural Gas Eagle Ford Shale Offshore Onshore Canada Production Capital Expenditure Realized Pricing $1,134 MM Net Debt2 $544 MM Adjusted EBITDAX2 $1.08 Adjusted Net Income per Share2 $8.20 Lease Operating Expense ($/BOE) 186 MBOEPD $23.08 / BBL NGL $1.84 / MCF Natural Gas $89.35 / BBL Oil $422 MM $2661 MM $129 MM Development Exploration Appraisal $28 MM
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883Q 2026 Earnings Presentation 3Q 2026 ASSET UPDA TES 1 Development CAPEX; excludes exploration costs of $12 MM Note: Production volumes and CAPEX exclude noncontrolling interest Eagle Ford Shale Brought 14 operated Catarina wells online Reduced cost per lateral foot by 26% in 2026 455 MMCFD 100% Natural Gas Brought eight wells online Realized $1.64/MCF versus $1.12/MCF AECO Tupper Montney Tupper MontneyKaybob Duvernay Lac Da Vang (Golden Camel)Offshore Canada Gulf of America 6 MBOEPD 64% Oil | 73% Liquids 54 MBOEPD 80% Oil | 87% Liquids Well program completed in 2Q; wells are producing in-line with plan Commenced production from Chinook #8 development well $13 MM CAPEX $3 MM CAPEX 44 MBOEPD 69% Oil | 87% Liquids $46 MM CAPEX $145 MM CAPEX1 Onshore Offshore 7 MBOPD 100% Oil Hibernia: 3 MBOPD $6 MM CAPEX 20 BOEPD 100% Oil Production rate represents 4 days of production in 3Q Drilling activity ongoing $45 MM CAPEX Terra Nova: 4 MBOPD
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993Q 2026 Earnings Presentation LAC DA VANG (GOLDEN CAMEL) ACHIEVES FIRST OIL 1 FSO: Floating storage and offloading vessel FIRST OIL IN UNDER 3 YEARS FROM SANCTION • Achieved first oil on September 27, 2026 • Ongoing ramp up expected to grow production to 3-5 MBOEPD in FY 2027 • 10-15 MBOEPD net peak production in 2028-2029 • 100 MMBOE estimated gross recoverable resource • Gross CAPEX of ~$10 / BOE • $8 - $10 / BOE operating costs over the life of the field Lac Da Vang 2026 Key Milestones Timing Launch FSO1 2Q 2026 Complete Pipeline Work 2Q 2026 Install Platform Topsides 3Q 2026 Install FSO1 3Q 2026 First Oil 3Q 2026 Lac Da Vang Platform A and Drilling Rig New Pic
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10103Q 2026 Earnings Presentation Proven Offshore Expertise Data-driven portfolio with diverse shallow and deepwater capital-efficient projects Aligns with Global Energy Needs Sustained investment in conventional oil to meet long-term energy demand Sustainable, Organic Growth Strategy balances existing producing assets with high-impact exploration prospects EXPLORING BEYOND SHALE 103Q 2026 Earnings Presentation Leveraging unique offshore capabilities to drive shareholder value Gulf of America Côte d’lvoire Vietnam Exploration Focus Areas Morocco Mauritania
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11113Q 2026 Earnings Presentation EXECUTED EXPLORA TION PROGRAM AS PLANNED Vietnam1 Exploration and appraisal LDT North-1X Oil Discovery, 2H 2026 HSV-4X Dry Hole, 2H 2026 HSV-3X Successful Appraisal, 1H 2026 Gulf of America Infrastructure-led exploration Banjo #1 Oil Discovery, 1H 2026 Cello #1 Oil Discovery, 1H 2026 Côte d’Ivoire Appraisal program ongoing Bubale West-1X Successful Appraisal, 2H 2026 Bubale-1X Oil Discovery, 1H 2026 Caracal-1X Non-commercial, 1H 2026 HSV-2X Successful Appraisal, 1H 2026 Civette-1X Non-commercial, 1H 2026 1 LDT-North in Vietnam refers to Lac Da Trang (White Camel) North, and HSV refers to Hai Su Vang (Golden Sea Lion) Note: Murphy and its subsidiaries have an 85-90% WI in Côte d’Ivoire blocks, 40% WI in Vietnam, and 48.5% WI in Cello and Banjo
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12123Q 2026 Earnings Presentation Implied per unit cost $/BOE 1 P ortfolio Success Drives Lower-Cost Reserve Growth Organic Growth Drives Long-term Value Buying versus Finding Resources • Murphy’s recent discoveries have added resources at an estimated cost under $2 per BOE • Portfolio success absorbs dry hole costs while supporting attractive reserve replacement • Murphy’s exploration capabilities provide a differentiated path to long-term value creation 1 Represents PUD volumes purchased (sourced from public filings) divided by implied purchase price for PUDs based on Enverus and S&P estimates 2 Based on total lease acquisition cost and estimated well locations from top two bidders in 2Q 2026 BLM lease sale; sourced from public filings, Enverus and S&P data 2 $0 $1 $2 $3 $4 $5 $6 $7 Hai Su Vang Finding Cost Lac Da Vang Finding Cost Recent Peer Onshore Acquisition 1 Recent Peer Onshore Acquisition 2 Permian Lease Sale Based on cost of exploration and appraisal program and midpoint of current resource range estimate $0.8 Murphy Finding Cost $1.5 $4 $6 ≤$2 per BOE $6 1 EXPLORA TION CREA TES A LOWER-COST P A TH TO RESERVE REPLACEMENT
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13133Q 2026 Earnings Presentation HAI SU VANG SPOTLIGHT 133Q 2026 Earnings Presentation One of the Cuu Long Basin’s Largest Discoveries Source: S&P Upstream Solutions 1 Post Appraisal Recoverable Resource Range of 200 – 300 MMBOE with a 250 MMBOE midpoint Cuu Long Basin
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1414 3Q 2026 Earnings Presentation VIETNAM EXPLORA TION AND APPRAISAL Acreage as of November 3, 2026 143Q 2026 Earnings Presentation Discovery Appraisal Field Development ProjectMurphy Discovery Murphy WI Block Select Murphy Exploration Inventory Platform FSO BLOCK 15-1/05 Dry Hole
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1515 3Q 2026 Earnings Presentation VIETNAM EXPLORA TION AND APPRAISAL 1 Murphy 40% (Operator), PetroVietnam Exploration Production 35%, SK Earthon 25%, Murphy took operatorship of Block 15-1/05 in 2018 Lac Da T rang (White Camel) North Discovery • Block 15-1/051 • Discovery announced at Lac Da Trang North-1X in October 2026 • 131 feet of net oil pay from one reservoir • Potential future tie-back to Lac Da Vang development Lac Da Hong (Pink Camel) Discovery • Block 15-1/051 • Discovery announced May 2025 • Encountered 106 feet of net oil pay from one reservoir • High quality, 38-degree API oil • Potential future tie-back to Lac Da Vang development Hai Su Vang (Golden Sea Lion) Appraisal • Hai Su Vang-1X exploration well in Block 15-2/171; spud 3Q 2024 • Discovery announced at Hai Su Vang–1X in 1Q 2025 • Encountered 370 feet of net oil pay from two reservoirs • High quality, 37-degree API oil • Three-well appraisal campaign over 2025 and 2026 • Hai Su Vang-2X: Block 15-2/17, spud in 4Q 2025 • Hai Su Vang-3X: Block 15-1/05, spud in 1Q 2026 • Hai Su Vang-4X: Block 15-2/17, spud in 2Q 2026 • Post-appraisal recoverable resource range of 200 to 300 MMBOE • Reviewing development concepts, FID expected in 4Q 2027 Lac Da T rang (White Camel) Discovery • Block 15-1/051 • Discovery announced May 2019 • Potential future tie-back to Lac Da Vang development Lac Da Nau (Brown Camel) Discovery • Block 15-1/051 • Discovery announced November 2009 • Potential future tie-back to Lac Da Vang development
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1616 3Q 2026 Earnings Presentation Gas Processing Facility 40 miles from Bubale-1X BUBALE DISCOVERY IN CÔTE D’IVOIRE Note: Acreage as of November 3, 2026 1 Block CI-709 Murphy 90% (Operator), Block CI-103 Murphy 85% (Operator) Discovery Announced in June 2026 Bubale-1X Bubale West–1X Successful Appraisal • Encountered 88 feet of net oil pay in the Turonian reservoir • Additional hydrocarbons encountered in the deeper Albian • Initial assessment indicates high-quality oil Bubale-1X Discovery Well • Encountered 100 feet of net oil pay across the Turonian and Cenomanian reservoirs • Initial assessment indicates high-quality oil • Pre-drill mean to upward gross recoverable resource estimate: 340 – 850 MMBOE Next Steps • 2 to 4 appraisal wells planned for the next 18 to 24 months 163Q 2026 Earnings Presentation Paon CI-502 CI-102 CI-531 CI-103 CI-709 Civette-1X Non-Commercial Caracal-1X Non-Commercial 250 miles AFRIC A Bubale West -1X Murphy WI Block Other Block Discovery Appraisal
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17173Q 2026 Earnings Presentation LOOKING BACK: OFFSHORE PORTFOLIO EXP ANSION IN 2026 173Q 2026 Earnings Presentation PORTFOLIO OUTCOMES Hai Su Vang 200 – 300 MMBOE Post-appraisal resource estimate Cello & Banjo Online in 4Q 2027 4 MBOEPD expected IP Bubale 340 – 850 MMBOE Pre-drill resource estimate Lac Da Trang North Resource expansion Future tie back to Lac Da Vang Lac Da Vang 100 MMBOE resource estimate 10 – 15 MBOEPD net peak LAC DA VANG VIETNAM First Oil 1 Mauritania agreements finalized November 2026; Cameroon agreements are expected to be finalized by year end 1 1
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18183Q 2026 Earnings Presentation 2026 CAPIT AL AND PRODUCTION GUIDANCE
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19193Q 2026 Earnings Presentation Producing Asset Oil (BOPD) NGLs (BOPD) Gas (MCFD) To t a l (BOEPD) US – Eagle Ford Shale 26,700 7,200 33,500 39,500 – Gulf of America excl. NCI1 45,200 3,100 37,400 54,500 Canada – Tupper Montney 100 - 426,500 71,200 – Kaybob Duvernay 3,100 500 8,400 5,000 – Offshore 6,800 - - 6,800 Vietnam 700 - 400 800 Brunei 200 - - 200 Total 82,800 10,800 506,200 178,000 4Q Production Volume (BOEPD) excl. NCI1 174,000 – 182,000 4Q CAPEX ($ MM) excl. NCI 2 $190 4Q Exploration Expense ($ MM) 3 $40 4Q 2026 GUIDANCE Numbers may not add due to rounding 1 Excludes noncontrolling interest of MP GOM of 5,500 BOPD oil, 200 BOPD NGLs and 1,500 MCFD natural gas 2 Excludes noncontrolling interest of MP GOM of $5 MM 3 Primarily G&G costs, no dry hole costs in 4Q 4Q 2026 Production Guidance by Product 47% 6% 47% Oil NGL Natural Gas0 100
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20203Q 2026 Earnings Presentation FY 2026 GUIDANCE Producing Asset Oil (BOPD) NGLs (BOPD) Gas (MCFD) To t a l (BOEPD) US – Eagle Ford Shale 28,000 6,900 33,600 40,500 – Gulf of America excl. NCI1 45,000 3,700 44,100 56,100 Canada – Tupper Montney 200 - 400,100 66,800 – Kaybob Duvernay 3,600 500 8,200 5,500 – Offshore 7,700 - - 7,700 Vietnam 200 - 100 200 Brunei 200 - - 200 Total 84,900 11,100 486,100 177,000 Full Year 2026 Production Volume (BOEPD) excl. NCI1 176,000 – 178,000 Full Year 2026 CAPEX ($ MM) excl. NCI 2 $1,500 - $1,600 Full Year Exploration Expense ($ MM) 3 $190 Numbers may not add due to rounding 1 Excludes noncontrolling interest of MP GOM of 5,400 BOPD oil, 200 BOPD NGLs and 1,800 MCFD natural gas 2 Excludes noncontrolling interest of MP GOM of $70 MM 3 Includes dry hole expense of $90 MM 4 Non-operated working interest averages 24 percent FY 2026 Onshore Wells Online 0 10 20 30 1Q 2026A 2Q 2026A 3Q 2026A 4Q 2026E Eagle Ford Shale (Non-Op)4 Eagle Ford Shale Tupper Montney Kaybob Duvernay
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21213Q 2026 Earnings Presentation APPENDIX
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22223Q 2026 Earnings Presentation STRA TEGY DRIVES LONG-TERM SHAREHOLDER VALUE EXPLORE DEVELOP DELIVER 223Q 2026 Earnings Presentation Lac Da Vang (Golden Camel): first oil in Vietnam in 3Q 2026 Gulf of America: Executing high- return, oil weighted projects Eagle Ford Shale: Accelerating activity to fund long-term growth Tupper Montney: Maintaining gross production near 500 MMCFD Long-term organic growth Return of minimum of 50% of adjusted FCF to shareholders Disciplined reinvestment rate, balancing financial stewardship, growth, and free cash flow Strong balance sheet and leverage metrics FINANCIAL DISCIPLINE AND OPERATIONAL EXCELLENCE Executing appraisal program in Côte d’Ivoire Progressing Vietnam discoveries toward a material business in the 2030s Prioritizing infrastructure-led exploration in the Gulf of America Entering frontier and emerging basins with high potential
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23233Q 2026 Earnings Presentation Our Differentiated Expertise Our T rack Record 2x Portfolio depth to double offshore reserves via exploration ~40% Faster discovery-to-first-oil than the industry average ~99%2 Uptime for key offshore facilities driven by ongoing operational excellence DELIVERING VALUE THROUGH EXPLORA TION Confirm a working petroleum system Define resource extent and commerciality Confirm recoverable resource potential Select an optimal development concept Commit capital and execute development Identify material growth opportunities DISCOVERY APPRAISAL RESOURCE DEFINITION CONCEPT SELECTION FID & DEVELOPMENT FIRST OIL Generate cash flow and shareholder returns 67% Exploration success rate since 2024 Differentiated Exploration Culture Unique culture helps attract and retain top talent Data-led Regional Insight Establishes geologic context to frame prospectivity Disciplined P ortfolio Management Deep portfolio that balances risk and resource potential Development Expertise and T rack Record Shallow and deepwater expertise Converts Exploration Success into Shareholder Returns EXPLORATION International Portfolio Bubale HSV (Golden Sea Lion)1 Cello & Banjo Fields LDV (Golden Camel)1 1 HSV is now moving into development planning phase; LDV achieved first oil in 3Q 2026 2 Reflects uptime for Pioneer and King’s Quay facilities in 2025
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24243Q 2026 Earnings Presentation 2026 SUST AINABILITY REPORT HIGHLIGHTS CONTINUED ENVIRONMENTAL STEWARDSHIP STRONG GOVERNANCE OVERSIGHT POSITIVEL Y IMP ACTING OUR PEOPLE AND COMMUNITIEShave received El Dorado Promise Scholarships since 2007 ~4,900 STUDENTS In Charitable Contributions from 2020 to 2025 ~$23 MILLION Professional and Technical training hours completed 17,400+ Total Recordable Incident Rate (TRIR) from 2019 to 2025 FROM 2019 TO 2025 15% - 20% REDUCTION IN GHG EMISSIONS INTENSITY* by 2030 compared to 2019 38% REDUCTION since 2019 ON TRACK ZERO ROUTINE FLARING by 2030 49% REDUCTION in routine flaring volumes since 2019 ON TRACK THIRD-PARTY ASSURANCE Sixth year of GHG Scope 1 and 2 data First year of key water data SUSTAINABILITY METRICS In Annual Incentive Plan enhanced to include methane intensity and water recycling ratio CYBERSECURITY AND DIGITAL RISK Established, Adaptive Artificial Intelligence (AI) Governance for secure, legal and ethical use GHG INTENSITY GOAL In Annual Incentive Plan since 2021 WELL-DEFINED BOARD AND MANAGERIAL OVERSIGHT AND MANAGEMENT OF SUSTAINABILITY MATTERS INTERACTIONS WITH INVESTORS 350+ BEST PLACE FOR WORKING PARENTS® from 2022 to 2026 U.S. PRESIDENT’S VOLUNTEER SERVICE AWARD from the Houston Food Bank for 2021 to 2025 volunteer efforts COMMUNITY HONOR ROLL RECOGNITION by United Way for more than 10 years CLIMATE GOALS 38% METHANE INTENSITY 58% FLARING INTENSITY 144% PRODUCED WATER RECYCLED *Scope 1 and 2 AWARDS GHG 54%
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25253Q 2026 Earnings Presentation GULF OF AMERICA EXPLORA TION Exploration Program • Announced Banjo #1 and Cello #1 discoveries in January 2026 • Sanctioned development of Banjo and Cello fields • Targeting first oil in 4Q 2027 with combined average net production contribution of approximately 4 MBOEPD in 2028 Future Opportunities • Secured six exploration blocks from the August 2026 Gulf of America federal offshore lease sale • Secured 14 blocks in 1Q 2026 from the December 2025 federal offshore lease sale • Evaluating 2027 exploration program Note: Acreage as of November 3, 2026 Gulf of America Exploration Focus Area Miles 500 Offshore PlatformMurphy WI BlockDiscovery Key Exploration Project Kodiak Front Runner Medusa Guilder Silver Dollar West Silver Dollar Liberty Longclaw Powerball Ninja Cascade ChinookLucius St. Malo Whydah/Leibniz/ Guadalupe Delta House Rushmore King’s Quay Ocotillo #1 Dalmatian S. Banjo #1 Zephyrus Cello #1 Miles 30 Banjo #1 Cello #1 Delta House MC385 MC386 MC431 MarmalardMC255 MC299 MC300 SOB II MC301 Producing Oil Field Expanding Our Opportunity Set for the Next Decade
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26263Q 2026 Earnings Presentation GULF OF AMERICA Note: Acreage as of November 3, 2026 1 Excluding noncontrolling interest 2 Anadarko is a wholly-owned subsidiary of Occidental Petroleum PRODUCING ASSETS Asset Operator Murphy WI1 Cascade Murphy 80% Chinook Murphy 86% Clipper Murphy 80% Dalmatian Murphy 56% Front Runner Murphy 50% Habanero Shell 27% Khaleesi Murphy 34% Kodiak Kosmos 59% Lucius Anadarko2 16% Marmalard Murphy 24% Marmalard East Murphy 65% Medusa Murphy 48% Mormont Murphy 34% Neidermeyer Murphy 52% Powerball Murphy 75% Samurai Murphy 50% Son of Bluto II Murphy 27% St. Malo Chevron 20% Tahoe W&T 24% Zephyrus Beacon 8% Gulf of America Exploration Area Offshore Platform FPSO Murphy WI BlockDiscovery Key Exploration Project Miles 500 Kodiak Front Runner Medusa Guilder Silver Dollar West Silver Dollar Liberty Longclaw Powerball Ninja Cascade ChinookLucius St. Malo Whydah/Leibniz/ Guadalupe Delta House Rushmore King’s Quay Ocotillo #1 Dalmatian S. Zephyrus Banjo #1 Cello #1
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27273Q 2026 Earnings Presentation OFFSHORE DEVELOPMENT OPPORTUNITIES Multi-Year Inventory of High-Return Projects Diversified, Low Breakeven Opportunities in Offshore P ortfolio • Identified offshore projects provide a multi-year inventory • Ongoing exploration efforts will further expand offshore portfolio Identified Offshore Project Portfolio Percent of Total Resource by Area Note: As of December 31, 2025 Breakeven rates are based on current estimated costs at a 10% rate of return Gulf of America Offshore CanadaSE Asia Resource with First Oil by Year Percent of Total Resource by Year Projects Include 28 projects 15 projects 240 MMBOE of total resources with < $40 / BBL WTI breakeven 30 MMBOE of total resources with > $40 / BBL WTI breakeven 58% 35% 7% 28% 6% 7% 17% 2% 40% 2026 2027 2028 2029 2030 2031+ ~270 MMBOE 43 Projects
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28283Q 2026 Earnings Presentation Kaybob Duvernay 420 Locations ~50 years of inventory < $57 / BBL WTI Provides optionality to produce more oil NORTH AMERICA ONSHORE LOCA TIONS Robust Inventory With Low Breakeven Rates Diversified, Low Breakeven P ortfolio Multi-basin portfolio provides optionality in all price environments Tupper Montney 720 Locations ~50 years of inventory Capital efficient, low breakeven wells Note: As of December 31, 2025 Breakeven rates are based on estimated costs of a 4-well pad program at a 10% rate of return Tupper Montney assumes an annual 15-well program. Eagle Ford assumes an annual 30-well program, Kaybob Duvernay assumes an annual 5-well program Eagle Ford Shale 1,040 Locations ~25 years of inventory < $55 / BBL WTI 0 100 200 300 400 500 <$35 $35-$45 $45-$55 >$55 0 50 100 150 200 250 <$1.42 $1.42-$1.44 $1.44-$1.48 >$1.48 Breakeven Natural Gas Price (US$ / MCF AECO) Breakeven Oil Price (US$ / BBL WTI) Breakeven Oil Price (US$ / BBL WTI) Remaining Locations 0 30 60 90 120 150 180 <$47 $47-$52 $52-$57 >$57
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29293Q 2026 Earnings Presentation CURRENT FIXED PRICE CONTRACTS Commodity T ype Volumes (MMCF/D) Price ($/MCF) Start Date End Date Natural Gas Fixed Price Forward Sales at AECO1 59 C$3.00 10/1/2026 12/31/2026 Natural Gas Fixed Price Forward Sales at AECO1 9.5 C$3.14 1/1/2027 12/31/2027 Note: As of November 3, 2026 1 These contracts are for physical delivery of natural gas volumes at a fixed price, with no mark-to-market income adjustment AECO Price Risk Mitigation – Tupper Montney, Canada
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30303Q 2026 Earnings Presentation 2025 PROVED RESERVES 24% 20% 56% • Total proved reserves of 715 MMBOE at YE 2025, 103% total reserve replacement • Pioneer FPSO acquisition added ~16 MMBOE of proved reserves in the Cascade and Chinook fields • 57% proved developed reserves and 41% liquids-weighting • Proved reserve life of 11 years Note: Production volumes, sales volumes, reserves and financial amounts exclude noncontrolling interest, unless otherwise stated Reserves are based on SEC YE 2025 audited proved reserves 715 MMBOE 2025 Proved Reserves By Area US Onshore Offshore Canada Onshore 58% 60% 57% 59% 57% 0 100 200 300 400 500 600 700 800 YE 2021 YE 2022 YE 2023 YE 2024 YE 2025 Proved Developed Proved Undeveloped Proved Reserves MMBOE 36% 5% 59% 41% Liquids-Weighted 2025 Proved Reserves By Product Oil NGL Natural Gas Maintaining Proved Reserves and Reserve Life
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31313Q 2026 Earnings Presentation SUPPLEMENT AL INFORMA TION Capital Allocation Plan The timing and magnitude of debt reductions and share repurchases will largely depend on oil and natural gas prices, developm ent costs and operating expenses, as well as any high- return investment opportunities. Because of the uncertainties around these matters, it is not possible to forecast how and wh en the company’s targets might be achieved. Share Repurchase Program The share repurchase program allows the company to repurchase shares through a variety of methods, including but not limited to open market purchases, privately negotiated transactions and other means in accordance with federal securities laws, such as through Rule 10b5 -1 trading plans and under Rule 10b-18 of the Exchange Act. This repurchase program has no time limit and may be suspended or discontinued completely at any time without prior notice as determined by the compa ny at its discretion and dependent upon a variety of factors. Adjusted EBITDAX (Non-GAAP) Murphy defines Adjusted EBITDAX as net income (loss) attributable to Murphy before interest, taxes, depreciation, depletion a nd amortization (DD&A), exploration expense, impairment expense, discontinued operations, foreign exchange gains and losses, mark-to-market gains and losses on derivative instruments, accretion of asset retirement obligations and certain other items that management believes affect comparability between periods. Adjusted Net Income and Adjusted Net Income per Share (Non -GAAP) Murphy defines Adjusted Net Income as net income attributable to Murphy adjusted to exclude discontinued operations and certa in other items that affect comparability between periods. Murphy defines Adjusted Net Income per share as Adjusted Net Income divided by average diluted shares. Free Cash Flow (Non-GAAP) Murphy defines free cash flow as net cash provided by continuing operations activities, before non- cash working capital changes, less property additions and dry hole costs. Net Debt (Non-GAAP) Murphy defines Net Debt as total short- and long-term debt, including finance lease obligations, net of cash and cash equivalents. Leverage (Non-GAAP) Murphy defines leverage as total debt, including finance lease obligations, divided by adjusted earnings before interest, tax es, depreciation and amortization (EBITDA) attributable to Murphy (non-GAAP). See reconciliation slide for calculation.
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32323Q 2026 Earnings Presentation GLOSSARY OF ABBREVIA TIONS AECO: Alberta Energy Company, the Canadian benchmark price for natural gas API: American Petroleum Institute BBL: Barrels (equal to 42 US gallons) BCF: Billion cubic feet BCFE: Billion cubic feet equivalent BN: Billions BOE: Barrels of oil equivalent (1 barrel of oil or 6,000 cubic feet of natural gas) BOEPD: Barrels of oil equivalent per day BOPD: Barrels of oil per day CAGR: Compound annual growth rate D&C: Drilling and completions DD&A: Depreciation, depletion and amortization EBITDA: Income from continuing operations before taxes, depreciation, depletion and amortization, and net interest expense EBITDAX: Income from continuing operations before taxes, depreciation, depletion and amortization, net interest expense, and exploration expenses EFS: Eagle Ford Shale EUR: Estimated ultimate recovery F&D: Finding and development FID: Final Investment Decision G&A: General and administrative expenses GOA: Gulf of America IP: Initial production rate LOE: Lease operating expense MBO: Thousands barrels of oil MBOE: Thousands barrels of oil equivalent MBOEPD: Thousands of barrels of oil equivalent per day MBOPD: Thousands of barrels of oil per day MCF: Thousands of cubic feet MCFD: Thousands cubic feet per day MM: Millions MMBOE: Millions of barrels of oil equivalent MMCF: Millions of cubic feet MMCFD: Millions of cubic feet per day NGL: Natural gas liquids ROR: Rate of return R/P: Ratio of reserves to annual production SCF: Standard cubic feet TCF: Trillion cubic feet WI: Working interest WTI: West Texas Intermediate (a grade of crude oil)
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33333Q 2026 Earnings Presentation NON-GAAP DEFINITIONS AND RECONCILIA TIONS (Millions of dollars) Three Months Ended – Sep 30, 2026 Three Months Ended – Sep 30, 2025 Nine Months Ended – Sep 30, 2026 Nine Months Ended – Sep 30, 2025 Net Cash provided by continuing operations activities (GAAP)1 540.5 339.4 1,517.6 998.2 Exclude: increase (decrease) in non-cash working capital (25.5) 28.4 15.0 20.5 Operating cash flow excluding working capital adjustments 515.0 367.8 1,532.6 1,018.7 Less: property additions and dry hole costs2 (466.8) (149.0) (1,333.0) (827.0) Free Cash Flow (Non-GAAP) 48.2 218.8 199.6 191.7 Free Cash Flow Murphy defines free cash flow (a non-GAAP financial measure) as net cash provided by continuing operations activities, before no n-cash working capital changes, less property additions and dry hole costs. Management believes free cash flow is important information to provide as it is used by management to evaluate the Company’s ability to generate additional cash from business operations. Free cash flow is a non-GAAP financial measure and should not be considered a substitute for other financial measures as determined in accordance with accounting principles generally accepted in the United States of America (GAAP). Murphy’s definition of free cash flow is limited and does not represent residual cash flows available for discretionary expen ditures due to the fact that the measure does not deduct the payments required for debt service and other obligations or payments made for business acquisitions. Free cash flow as report ed by Murphy may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with other performance measures prepared in accordan ce with GAAP. Therefore, we believe it is important to view free cash flow as supplemental to our entire statement of cash flows. The following list of Non-GAAP financial measure definitions and related reconciliations is intended to satisfy the requirements of Regulation G of the Securities Exchange Act of 1934, as amended. This information is historical in nature. Murphy undertakes no obligation to publicly update or revise any Non-GAAP financial measure definitions and related reconciliations. 1 Includes noncontrolling interest in MP GOM 2 Property additions for the nine months ended September 30, 2025 include a payment of $125.0 million for the purchase of a floating production, storage, and offloading vessel in the Gulf of America, including amounts attributable to a noncontrolling interest in MP GOM.
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34343Q 2026 Earnings Presentation NON-GAAP DEFINITIONS AND RECONCILIA TIONS Adjusted Net Income per Share Murphy defines Adjusted Net Income (a non-GAAP measure) as net income attributable to Murphy adjusted to exclude discontinued op erations and certain other items that affect comparability between periods. Murphy defines Adjusted Net Income per Share (a non -GAAP financial ratio) as Adjusted Net Income divided by average diluted shares. Management believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial r esults. Murphy’s definition of Adjusted Net Income per Share is limited and does not represent the company’s long-term operating costs or residual cash flows available for discretionary expend itures or returns to shareholders. Adjusted Net Income and Adjusted Net Income per Share are non-GAAP financial measures and may not be comparable to similarly titled measures used by oth er companies and should not be considered a substitute for measures prepared in accordance with U.S. GAAP. Therefore, we believe it is important to view Adjusted Net Inc ome and Adjusted Net Income per Share as supplemental to our entire financial statements. 1 Excludes noncontrolling interest in MP GOM (Millions of dollars, except per-share amounts) Three Months Ended – Sep 30, 2026 Three Months Ended – Sep 30, 2025 Nine Months Ended – Sep 30, 2026 Nine Months Ended – Sep 30, 2025 Net income (loss) attributable to Murphy (GAAP)1 171.1 (3.0) 456.3 92.3 Reconciliation adjustments: Discontinued operations (gain) loss 0.2 0.5 1.2 (0.2) Impairment of assets¹ - 92.0 - 92.0 Foreign exchange (gain) loss (1.5) (13.4) (20.1) 20.9 Unrealized gain on derivative instruments - (2.5) - (3.9) Income tax (benefit) expense related to adjustments 0.4 (15.5) 5.2 (23.8) Tax benefits on investments in foreign areas (11.8) - (11.8) - Adjusted net income from continuing operations attributable to Murphy (Non-GAAP) 158.4 58.1 430.8 177.3 Net income (loss) from continuing operations per average diluted share (GAAP) 1.17 (0.02) 3.14 0.64 Adjusted net income from continuing operations per average diluted share (Non-GAAP) 1.08 0.41 2.95 1.23
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35353Q 2026 Earnings Presentation NON-GAAP DEFINITIONS AND RECONCILIA TIONS Adjusted EBITDAX Murphy defines Adjusted EBITDAX as net income (loss) attributable to Murphy before interest, taxes, depreciation, depletion a nd amortization (DD&A), exploration expense, impairment expense, discontinued operations, foreign exchange gains and losses, mark-to-market gains and losses on derivative instruments, accretion of asset retirement obligations and certain other items that management believes affect comparability between periods. Management believes this information may be useful to in vestors and analysts to gain a better understanding of the Company’s financial results. Murphy’s definition of Adjusted EBITDAX is limited and does not wholly represent the company’s a bility to service debt due to the absence of other obligations or payments, and the accrual nature of adjusted EBITDAX. Adjusted EBITDAX is a non- GAAP financial measure and may not be comparable to similarly titled measures used by other companies and should not be considered a substitute for measures prepared in accordance with U.S. GAAP. Therefore, we believe it is important to view Adjusted EBITDAX as supplemental to our entire financial statements. 1 Excludes noncontrolling interest in MP GOM (Millions of dollars) Three Months Ended – Sep 30, 2026 Three Months Ended – Sep 30, 2025 Nine Months Ended – Sep 30, 2026 Nine Months Ended – Sep 30, 2025 Net income (loss) attributable to Murphy (GAAP)1 171.1 (3.0) 456.3 92.3 Income tax expense 39.3 4.1 166.3 37.9 Interest expense, net 24.2 24.7 78.1 73.3 Depreciation, depletion and amortization expense 1 264.1 275.0 764.9 713.2 Exploration expenses1 33.0 32.5 155.1 57.3 EBITDAX attributable to Murphy (Non-GAAP)1 531.7 333.3 1,620.7 974.0 Impairment of assets¹ - 92.0 - 92.0 Foreign exchange (gain) loss (1.5) (13.4) (20.1) 20.9 Accretion of asset retirement obligations1 13.5 13.2 39.8 38.6 Unrealized (gain) loss on derivative instruments - (2.5) - (3.9) Discontinued operations (income) loss 0.2 0.5 1.2 (0.2) Adjusted EBITDAX attributable to Murphy (Non-GAAP) 1 543.9 423.1 1,641.6 1,121.4
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36363Q 2026 Earnings Presentation NON-GAAP DEFINITIONS AND RECONCILIA TIONS Net Debt Murphy defines Net Debt (a non-GAAP financial measure) as total short- and long-term debt, including finance lease obligations, net of cash and cash equivalents. Management believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial position. Murphy’s definition of net debt is limited and does not wholly represent the company’s ability to service debt due to the absence of other obligations or payments. Net Debt is a non -GAAP financial measure and may not be comparable to similarly titled measures used by other companies and should not be considered a substitute for measures prepared in accordance with U.S. GAAP. Therefore, we believe it is important to view Net Debt as supplemental to our entire financial statements. (Millions of dollars) September 30, 2026 December 31, 2025 Current maturities of long-term debt, finance lease 11.2 2.5 Total Notes Payable, net of unamortized discount 1,539.6 1,272.4 Finance Lease Obligations, due through 2039 83.5 10.1 Senior unsecured revolving credit facility - 100.0 Total Debt (GAAP) 1,634.3 1,385.0 Less: Cash and cash equivalents1 500.3 377.2 Net Debt (Non-GAAP) 1,134.0 1,007.8 1 Includes noncontrolling interest in MP GOM
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37373Q 2026 Earnings Presentation NON-GAAP DEFINITIONS AND RECONCILIA TIONS Leverage Murphy defines leverage (a non-GAAP financial ratio) as total debt, including finance lease obligations, divided by adjusted ear nings before interest, taxes, depreciation and amortization (EBITDA)1 for the last twelve months attributable to Murphy2 (non-GAAP). Management believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial position. Murphy’s definition of leverage and adjusted EBITDA is limited and does not wholly represent the company’s ability to service debt due to the absence of other obligations or payments, and the accrual nature of adjusted EBITDA. Leverage and Adjusted EBITDA are non- GAAP financial measures and may not be comparable to similarly titled measures used by other companies and should not be considered a substitute for measures prepared in accordance with U.S. GAAP . Therefore, we believe it is important to view leverage and adjusted EBITDA as supplemental to our entire financial statements. Three Months Ended Twelve Months Ended (Millions of dollars) September 30, 2026 June 30, 2026 March 31, 2026 December 31, 2025 September 30, 2026 Net income (loss) attributable to Murphy2 (GAAP) 171.1 232.2 53.0 11.9 468.2 Income tax expense 39.3 77.0 49.9 6.6 172.8 Interest expense, net 24.2 24.9 29.0 22.8 100.9 Depreciation, depletion and amortization expense 264.1 254.0 246.9 233.5 998.5 EBITDA attributable to Murphy2 (Non-GAAP) 498.7 588.1 378.8 274.8 1,740.4 Foreign exchange (gain) loss (1.5) (9.2) (9.4) 8.5 (11.6) Accretion of asset retirement obligations 13.5 13.4 13.0 12.9 52.8 Unrealized (gain) loss on derivative instruments - - - 2.2 2.2 Discontinued operations (income) loss 0.2 0.4 0.5 (0.3) 0.8 Adjusted EBITDA1 attributable to Murphy2 (Non-GAAP) 510.9 592.7 382.9 298.1 1,784.6 1 Murphy defines adjusted EBITDA as net income (loss) attributable to Murphy before interest, taxes, depreciation, depletion and amortization, impairment expense, discontinued operations, foreign exchange gains and losses, mark-to- market gains and losses on derivative instruments, accretion of asset retirement obligations and certain other items that management believes affect comparability between periods. 2 ‘Attributable to Murphy’ represents the economic interest of Murphy excluding a 20% noncontrolling interest in MP GOM. 3 Net Income attributable to Murphy (GAAP) for the last twelve months ended September 30, 2026. (Millions of dollars) Sep 30, 2026 Current maturities of long-term debt, finance lease 11.2 Total Notes Payable, net of unamortized discount 1,539.6 Finance Lease Obligations, due through 2039 83.5 Total Debt 1,634.3 Total Debt including finance lease obligations (GAAP) / Net Income3 (GAAP) 3.5x Leverage (Non-GAAP) 0.9x
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38383Q 2026 Earnings Presentation 2026 THIRD QUARTER EARNINGS ERIC M. HAMBLY PRESIDENT AND CHIEF EXECUTIVE OFFICER NOVEMBER 5, 2026 CONFERENCE CALL AND WEBCAST