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Announcement
Tuesday, 24 February 2026			Woodside Energy Group Ltd. ACN 004 898 962 Mia Yellagonga 11 Mount Street Perth WA 6000 Australia T +61 8 9348 4000 www.woodside.com   ASX: WDS NYSE: WDS

WOODSIDE RELEASES FULL-YEAR 2025 RESULTS

Woodside today reported record production of 198.8 million barrels of oil equivalent (MMboe), or 545 Mboe/day, for the full year 2025. The result was underpinned by outstanding production performance at Sangomar, producing at nameplate capacity for most of the year, and world-class reliability at our operated Pluto LNG and NWS Project assets.

Record production offset lower realised prices resulting in net profit after tax (NPAT) of $2,718 million (24% lower from 2024) and underlying NPAT of $2,649 million (8% lower from 2024).¹

The Directors have determined a final dividend of US 59 cents per share (cps), which brings the full-year fully franked dividend to US 112 cps and maintains payout ratio at the top of the range at 80%. The value of the full-year dividend is $2.1 billion.

Woodside Acting CEO Liz Westcott said the record annual production in 2025 exceeded the guidance range and unit production cost decreased 4% from 2024 to $7.8 per barrel of oil equivalent, demonstrating cost discipline.

“The outstanding full-year results reflected the disciplined execution of Woodside’s strategy, while maintaining safe, reliable and sustainable operations. Our strong underlying NPAT of $2.6 billion and free cashflow1 of $1.9 billion is a testament to the performance of the base business during a period of increased capital expenditure and softening prices.

“The strength of our base business has delivered returns for shareholders, with Woodside having returned approximately $11 billion in dividends since merger completion in 2022. At the same time, we are re-investing in the business and actively refining the portfolio, while maintaining a strong balance sheet and gearing within the targeted range.

“Keeping our people safe is always Woodside’s priority and in a year of increased activity, no high-consequence injuries were recorded. We marked significant safety milestones across our global portfolio, with Sangomar recording no injuries in its first 18 months of operations, and the Scarborough floating production unit marking three years of work without a single lost-time incident.

“We are delivering on our commitments by leveraging our proven operational excellence, demonstrated project execution and delivery and continued financial discipline to reward shareholders today, while positioning Woodside for future value and growth.

“Sangomar produced at nameplate capacity of 100,000 barrels per day for most of 2025 at almost 99% reliability. This translated into $2.6 billion of EBITDA (Woodside share) generated since start-up, demonstrating the asset’s value.¹,²

 

 

1	Non-IFRS financial measure. Refer to the glossary section of the attached presentation for the definition.

2	Consists of Sangomar FY2024 EBITDA of $849 million and FY2025 EBITDA of $1,702 million.

 

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Full-Year 2025 Results Briefing 24 February 2026 www.woodside.com

Disclaimer, important notes and assumptions Information This presentation has been prepared by Woodside Energy Group Ltd (“Woodside”). All information included in this presentation, including any forward-looking statements, reflects Woodside’s views held as at the date of this presentation and, except as required by applicable law, neither Woodside, its related bodies corporate, nor any of their respective officers, directors, employees, advisers or representatives (“Beneficiaries”) intends to, undertakes to, or assumes any obligation to, provide any additional information or update or revise any information or forward-looking statements in this presentation after the date of this presentation, either to make them conform to actual results or as a result of new information, future events, changes in Woodside’s expectations or otherwise. Past performance (including historical financial and operational information) is not necessarily a reliable indicator of future performance. This presentation may contain industry, market and competitive position data that is based on industry publications and studies conducted by third parties as well as Woodside’s internal estimates and research. While Woodside believes that each of these publications and third-party studies is reliable and has been prepared by a reputable source, Woodside has not independently verified the market and industry data obtained from these third-party sources and cannot guarantee the accuracy or completeness of such data. Accordingly, undue reliance should not be placed on any of the industry, market and competitive position data contained in this presentation. To the maximum extent permitted by law, neither Woodside, its related bodies corporate, nor any of their respective Beneficiaries, assume any liability (including liability for equitable, statutory or other damages) in connection with, any responsibility for, or make any representation or warranty (express or implied) as to, the fairness, currency, accuracy, adequacy, reliability or completeness of the information or any opinions expressed in this presentation or the reasonableness of any underlying assumptions. No offer or advice This presentation is not intended to and does not constitute, form part of, or contain an offer or invitation to sell to Woodside shareholders (or any other person), or a solicitation of an offer from Woodside shareholders (or any other person) or a solicitation of any vote or approval from Woodside shareholders (or any other person) in any jurisdiction. This presentation has been prepared without reference to the investment objectives, financial and taxation situation or particular needs of any Woodside shareholder or any other person. The information contained in this presentation does not constitute, and should not be taken as, financial product or investment advice. Woodside encourages you to seek independent legal, financial, taxation and other professional advice before making any investment decision. Forward-looking statements This presentation contains forward-looking statements. These statements may relate to Woodside’s business, goals, targets, aspirations, plans, expectations, market conditions, results of operations and financial condition, including, for example, but not limited to, outcomes of transactions, statements regarding long-term demand for Woodside’s products and services, development, completion and execution of Woodside’s projects, expectations regarding future capital expenditures and cash flow, the payment of future dividends and the amount thereof, future results of projects, operating activities and new energy products, expectations and plans for new energy products and lower-carbon services and investments in, and development of, new energy products and lower-carbon services, expectations and guidance with respect to production, capital and exploration expenditure and gas hub exposure, and expectations regarding the achievement of Woodside’s Scope 1 and 2 greenhouse gas emissions reduction and Scope 3 investment and emissions abatement targets (in each case on a net equity or gross equity basis as specified) and other and sustainability goals. All statements, other than statements of historical or present facts, are forward-looking statements and generally may be identified by the use of forward-looking words such as ‘aim’, ‘anticipate’, ‘aspire’, ‘believe’, ‘estimate’, ‘expect’, ‘forecast’, ‘foresee’, ‘guidance’, ‘intend’, ‘likely’, ‘may’, ‘objective’, ‘outlook’, ‘pathway’, ‘plan’, ‘potential’, ‘project’, ‘schedule’, ‘seek’, ‘should’, ‘strategy’, ‘strive’, ‘target’, ‘will’’ and other similar words or expressions. Forward-looking statements in this presentation are not guidance, forecasts, guarantees or predictions of future events or performance, but are in the nature of future expectations that are based on management’s current expectations and contingencies. Those statements and any assumptions on which they are based are subject to change without notice and are subject to inherent known and unknown risks, uncertainties, assumptions and other factors, many of which are beyond the control of Woodside, its related bodies corporate and their respective officers, directors, employees, advisers or representatives. Important factors that could cause actual results to differ materially from those in the forward-looking statements and assumptions on which they are based include, but are not limited to, fluctuations in commodity prices, actual demand for Woodside’s products, currency fluctuations, geotechnical factors, drilling and production results, gas commercialisation, development progress, operating results, engineering estimates, reserve and resource estimates, loss of market, industry competition, sustainability and environmental risks, related transition and physical risks, changes in accounting standards, political risks, the actions of third parties, project delay or advancement, regulatory approvals, the impact of armed conflict and political instability (such as the ongoing conflicts in Ukraine and in the Middle East) on economic activity and oil and gas supply and demand, cost estimates, legislative, fiscal and regulatory developments, including but not limited to those related to the imposition of tariffs and other trade restrictions, the effect of future regulatory or legislative actions on Woodside or the industries in which it operates, including potential changes to tax laws, the impact of general economic and financial market conditions, inflationary conditions, prevailing exchange rates and interest rates and conditions in financial markets, and risks associated with acquisitions, mergers and joint ventures, including difficulties integrating or separating businesses, uncertainty associated with financial projections, restructuring, increased costs and adverse tax consequences, and uncertainties and liabilities associated with acquired and divested properties and businesses. A detailed summary of the key risks relating to Woodside and its business can be found in the “Risk” section of Woodside’s most recent Annual Report released to the Australian Securities Exchange and in Woodside’s most recent Annual Report on Form 20-F filed with the United States Securities and Exchange Commission and available on the Woodside website at https://www.woodside.com/investors/reports-investor-briefings. You should review and have regard to these risks when considering the information contained in this presentation. If any of the assumptions on which a forward-looking statement is based were to change or be found to be incorrect, this would likely cause outcomes to differ from the statements made in this presentation. Investors are strongly cautioned not to place undue reliance on any forward-looking statements. Actual results or performance may vary materially from those expressed in, or implied by, any forward-looking statements. All forward-looking statements contained in this presentation reflect Woodside’s views held as at the date of this presentation and, except as required by applicable law, Woodside does not intend to, undertake to, or assume any obligation to, provide any additional information or update or revise any of these statements after the date of this presentation, either to make them conform to actual results or as a result of new information, future events, changes in Woodside’s expectations or otherwise.

Disclaimer, important notes and assumptions (continued) Disclosure of reserve information and cautionary note to US investors Woodside is an Australian company with securities listed on the Australian Securities Exchange and the New York Stock Exchange. Woodside reports its Proved (1P) Reserves in accordance with SEC regulations, which are also compliant with SPE-PRMS guidelines, and prepares and reports its Proved plus Probable (2P) Reserves and Best Estimate (2C) Contingent Resources in accordance with SPE-PRMS guidelines. Woodside reports all of its petroleum resource estimates using definitions consistent with SPE-PRMS. The SEC prohibits oil and gas companies, in their filings with the SEC, from disclosing estimates of oil or gas resources other than ‘reserves’ (as that term is defined by the SEC). In this presentation, Woodside includes estimates of quantities of oil and gas using certain terms, such as ‘proved plus probable (2P) reserves’, ‘best estimate (2C) contingent resources’, ‘reserves and contingent resources’, ‘proved plus probable’, ‘developed and undeveloped’, ‘probable developed’, ‘probable undeveloped’, ‘contingent resources’ or other descriptions of volumes of reserves, which include quantities of oil and gas that may not meet the SEC’s definitions of proved, probable and possible reserves, and which the SEC’s guidelines strictly prohibit Woodside from including in filings with the SEC. These estimates are by their nature more speculative than estimates of proved reserves and would require substantial capital spending over a significant number of years to implement recovery, and accordingly are subject to substantially greater risk of not being recovered by Woodside. In addition, actual locations drilled and quantities that may be ultimately recovered from Woodside’s properties may differ substantially. Woodside has made no commitment to drill, and likely will not drill, all drilling locations that have been attributable to these quantities. US investors are urged to consider closely the disclosures in Woodside’s filings with the SEC which are available at www.sec.gov. Assumptions Unless otherwise indicated, the targets set out in this presentation have been estimated on the basis of a variety of economic assumptions including: (1) US$70/bbl Brent long-term oil price, US$10/MMBtu long term JKM price, US$9/MMBtu long-term TTF price, US$3.50 long-term Henry Hub price (2024 real terms) and a long-term inflation rate of 2.0%; (2) currently sanctioned projects being delivered in accordance with their current project schedules; and (3) applicable growth opportunities being sanctioned and delivered in accordance with the target schedules provided in this presentation. These growth opportunities are subject to relevant project participant approvals, commercial arrangements with third parties and regulatory approvals being obtained in the timeframe contemplated or at all. Woodside expresses no view as to whether project participants will agree with and support Woodside’s current position in relation to these opportunities, or such commercial arrangements and regulatory approvals will be obtained. Additional assumptions relevant to particular targets or other statements in this presentation may be set out in the relevant slides. Any such additional assumptions are in addition to the assumptions and qualifications applicable to the presentation as a whole. Climate strategy and emissions data All greenhouse gas emissions data in this presentation are estimates, due to the inherent uncertainty and limitations in measuring or quantifying greenhouse gas emissions. Methodologies for measuring or quantifying greenhouse gas emissions may evolve as best practices continue to develop and data quality and quantity continue to improve. Woodside “greenhouse gas” or “emissions” information reported are Scope 1 greenhouse gas emissions, Scope 2 greenhouse gas emissions, and/or Scope 3 greenhouse gas emissions, each on a net equity basis, unless otherwise stated. For more information on Woodside's strategy and performance, including further details regarding Woodside’s targets, aspirations and goals and the underlying methodology, judgements, assumptions and contingencies, refer to Woodside’s 2025 Climate and Sustainability Summary, available on the Woodside website at https://www.woodside.com/sustainability and section 3.6 of Woodside’s 2025 Annual Report. The glossary and footnotes to this presentation provide clarification regarding the use of terms such as "lower-carbon“ under Woodside's strategy. A full glossary of terms used in connection with Woodside's strategy is contained in Woodside’s 2025 Annual Report. Non-IFRS Financial Measures Throughout this presentation, a range of financial and non-financial measures are used to assess Woodside’s performance, including a number of financial measures that are not defined in, and have not been prepared in accordance with, International Financial Reporting Standards (IFRS) and are not recognised measures of financial performance or liquidity under IFRS (Non-IFRS Financial Measures). These measures include EBIT, EBITDA, EBITDA excluding impairment, EBITDA margin, Gearing, Underlying NPAT, Average realised price, Unit production cost, Net debt, Liquidity, Free cash flow, Capital expenditure, Exploration expenditure, Return on Equity, Cash margin, Production cost margin, and Other cash cost margin. These Non-IFRS Financial Measures are defined in the glossary section of this presentation. A quantitative reconciliation of these measures to the most directly comparable financial measure calculated and presented in accordance with IFRS can be found in the Alternative Performance Measures section of Woodside’s 2025 Annual Report. Woodside’s management uses these measures to monitor Woodside’s financial performance alongside IFRS measures to improve the comparability of information between reporting periods and business units and Woodside believes that the Non-IFRS Financial Measures it presents provide a useful means through which to examine the underlying performance of its business. Undue reliance should not be placed on the Non-IFRS Financial Measures contained in this presentation and these Non-IFRS Financial Measures should be considered in addition to, and not as a substitute for, or as superior to, measures of financial performance, financial position or cash flows reported in accordance with IFRS. Non-IFRS Financial Measures are not uniformly defined by all companies, including those in Woodside’s industry. Accordingly, they may not be comparable with similarly titled measures and disclosures by other companies. Other important information All references to dollars, cents or $ in this presentation are to US currency, unless otherwise stated. References to “Woodside” may be references to Woodside Energy Group Ltd and/or its applicable subsidiaries (as the context requires). References and links to Woodside’s or third-party websites are provided for convenience only and are not incorporated by reference into this presentation. This presentation does not include any express or implied prices at which Woodside will buy or sell financial products. A securities rating is not a recommendation to buy, sell or hold securities and may be subject to revision or withdrawal at any time.

Notes to petroleum reserves and resources Unless otherwise stated, all petroleum resource estimates are quoted as at the effective date of 31 December 2025, net Woodside share. For details of Woodside’s year end 2025 reserves position, see the Reserves and Resources Statement included in the 2025 Annual Report. US Investors should refer to “Additional information for US investors concerning reserves and resources estimates” above. All numbers are internal estimates produced by Woodside. Estimates of reserves and contingent resources should be regarded only as estimates that may change over time as additional information becomes available. For offshore oil projects, the reference point is defined as the outlet of the floating production storage and offloading facility (FPSO) or platform, while for the onshore gas projects the reference point is defined as the outlet of the downstream (onshore) gas processing facility. ‘Reserves’ are estimated quantities of petroleum that have been demonstrated to be producible from known accumulations in which the company has a material interest from a given date forward, at commercial rates, under presently anticipated production methods, operating conditions, prices, and costs. Woodside reports reserves inclusive of all fuel consumed in operations. Proved reserves are estimated and reported in accordance with SEC regulations which are also compliant with the SPE-PRMS guidelines. SEC-compliant proved reserves estimates use a more restrictive, rules-based approach and are generally lower than estimates prepared solely in accordance with SPE-PRMS guidelines due to, among other things, the requirement to use commodity prices based on the average of first of month prices during the 12-month period in the reporting company’s fiscal year. Proved plus probable reserves are estimated and reported in accordance with SPE-PRMS guidelines which are not compliant with SEC regulations. Assessment of the economic value in support of an SPE-PRMS reserves and resources classification, uses Woodside Portfolio Economic Assumptions (Woodside PEAs). The Woodside PEAs are reviewed on an annual basis, or more often if required. The review is based on historical data and forecast estimates for economic variables such as product prices and exchange rates. The Woodside PEAs are approved by the Woodside Board. Specific contractual arrangements for individual projects are also taken into account. Woodside is not aware of any new information or data that materially affects the information included in the Reserves and Resources Update. All the material assumptions and technical parameters underpinning the estimates in the Reserves and Resources Update continue to apply and have not materially changed. Woodside uses both deterministic and probabilistic methods for the estimation of reserves and contingent resources at the field and project levels. All proved reserves estimates have been estimated using deterministic methods and reported on a net interest basis in accordance with the SEC regulations and have been determined in accordance with SEC Rule 4-10(a) of Regulation S-X. Unless otherwise stated, all petroleum estimates reported at the company or region level are aggregated by arithmetic summation by category. The aggregated proved reserves may be a conservative estimate due to the portfolio effects of arithmetic summation. ‘MMboe’ means millions (106) of barrels of oil equivalent. Natural gas volumes are converted to oil equivalent volumes via a constant conversion factor, which for Woodside is 5.7 Bcf of dry gas per 1 MMboe. All volumes are reported at standard oilfield conditions of 14.696 psi (101.325 kPa) and 60 degrees Fahrenheit (15.56 degrees Celsius). ‘Proved reserves’ are those quantities of crude oil, condensate, natural gas and NGLs that, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs and under existing economic conditions, operating methods, operating contracts, and government regulations. Proved reserves are estimated and reported on a net interest basis in accordance with the SEC regulations and have been determined in accordance with SEC Rule 4-10(a) of Regulation S-X. ‘Undeveloped reserves’ are those reserves for which wells and facilities have not been installed or executed but are expected to be recovered through future significant investments. ‘Probable reserves’ are those reserves which analysis of geological and engineering data suggests are more likely than not to be recoverable. Proved plus probable reserves represent the best estimate of recoverable quantities. Where probabilistic methods are used, there is at least a 50% probability that the actual quantities recovered will equal or exceed the sum of estimated proved plus probable reserves. Proved plus probable reserves are estimated and reported in accordance with SPE-PRMS guidelines and are not compliant with SEC regulations. The estimates of petroleum reserves and contingent resources are based on and fairly represent information and supporting documentation prepared by, or under the supervision of, Mr Benjamin Ziker, Woodside’s Vice President Reserves and Subsurface, who is a full-time employee of the company and a member of the Society of Petroleum Engineers. The reserves and resources estimates included in this announcement are issued with the prior written consent of Mr Ziker. Mr Ziker’s qualifications include a Bachelor of Science (Chemical Engineering) from Rice University (Houston, Texas, USA) and 27 years of relevant experience.

Strong results from disciplined execution $2.7 billion Net profit after tax (NPAT), $2.6 billion underlying NPAT4 $9.3 billion EBITDA4 $1.9 billion Free cash flow4 2025 key statistics Achieved record production with zero high-consequence injuries Delivered strong shareholder returns; total full-year dividends of $2.1 billion, 112 US cps fully franked Executing major development projects on budget and schedule Maintained strong balance sheet through disciplined management of liquidity and capital Achieved 2025 net equity Scope 1 and 2 GHG emissions reduction target of 15% below starting base1,2,3 This means net equity Scope 1 and 2 emissions for the 12-month period ending 31 December 2025 are targeted to be 15% lower than the starting base. Net equity Scope 1 and 2 GHG emissions reduction targets and aspiration are relative to a starting base of 6.27 Mt CO2-e which is representative of the gross annual average equity Scope 1 and 2 greenhouse gas emissions over 2016-2020 and which may be adjusted (up or down) for potential equity changes in producing or sanctioned assets with a final investment decision prior to 2021. Net equity emissions include the utilisation of carbon credits as offsets, inclusive of those required to meet regulatory obligations. 198.8 MMboe Production (545 Mboe/d)5 3. In relation to our 2025 equity Scope 1 and 2 GHG emissions, 1,283 kt CO2‑e carbon credits were retired in order to meet our target of 5,334 kt CO2‑e net equity Scope 1 and 2 GHG emissions. This includes retirement of carbon credits subsequent to the period, after full year 2025 gross equity Scope 1 and 2 GHG emissions were calculated and externally assured. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. Includes 1.2 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.

Generated $2.1 billion of dividends while investing in future growth Maximise Deliver Create ~98% Operated LNG reliability $7.8/boe Unit production cost First production Achieved at Beaumont New Ammonia 94% Scarborough completion On budget and on track for first LNG cargo Q4 20261,2 50% Trion completion On budget and targeting first oil 20281 18.2% Gearing, within target range of 10-20%1,5 $9.3 billion Liquidity1,5 4% 2% 38% New strategic partners Stonepeak and Williams for Louisiana LNG, Woodside’s expected exposure <60% of total capital expenditure3 $1.9 billion Sangomar revenue (Woodside share) 4.7 Mtpa Sale and purchase agreements for LNG signed in 2025 Refined portfolio Greater Angostura divestment and Chevron asset swap4 Achieved FID on Louisiana LNG 22% complete, on budget and targeting first LNG 20291 Percentage variance for all operational performance and financial outcomes reference 2025 versus 2024. As of 31 December 2025. Percentage completion for Scarborough Energy Project excludes Pluto Train 1 modifications. Woodside’s total capital expenditure for the Louisiana LNG Project is expected to be $9.9 billion against total project cost announced at FID of $17.5 billion. Completion is subject to customary conditions precedent and remains targeted for completion in H2 2026. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition.

Improved safety performance HCI is defined as Fatality and Permanent Impairment Injury (FPI) which aligns with International Association of Oil and Gas Producers (IOGP) definition for FPI. From 2022 to 2024 HCI was defined as an injury where the individual does not return to full health within six months. Under the 2025 definition there was one HCI in 2024 and two HCI in 2023. HCI was not reported in 2021. High-consequence injuries1 Process safety events Zero high-consequence injuries recorded in 2025 Tier 1 process safety event in May 2025, short term and localised Continued focus on operational discipline and learning culture Tier 1 Tier 2 0 2

Driving value from base business Average five-year operated LNG reliability ~98%, supporting reliable deliveries to end-customers Reduced unit production cost demonstrates cost discipline and high-quality asset base Maximising value through infill drilling (e.g. Pluto, Bass Strait, Shenzi) and optimisation (e.g. Atlantis Major Facility Expansion) Continuing to pursue brownfield opportunities such as GWF-4; five-well tieback with expected IRR ~30%1 Executing turnaround in 2026 at Pluto to install tie-ins for Scarborough Record production2 Production (MMboe) and unit production cost ($/boe) Unit production cost Production Figures are Woodside share, 50% interest. Capital expenditure is post final investment decision. Subject to the completion of the Woodside and Chevron asset swap. Refer to the announcement titled ‘Woodside simplifies portfolio and unlocks long-term value’, dated 19 December 2024. IRR and the payback period are a look forward from January 2025. Payback period is calculated from undiscounted cash flows, RFSU + approximately 2 years. 2025 includes 1.2 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector. Pre-merger Post-merger

Sangomar: continued to deliver exceptional performance Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. Consists of Sangomar FY2024 EBITDA of $849 million and FY 2025 EBITDA of $1,702 million. Includes -3.1 MMboe change to proved (1P) fuel reserves. Zero lost time injuries or process safety events since the FPSO departed the shipyard in December 2023 World-class production reliability of 98.7% $2.6 billion EBITDA (Woodside share) generated since start-up1 27.9 MMboe added to proved reserves (1P, Woodside share) with production exceeding expectations2 Sangomar FPSO Léopold Sédar Senghor, December 2025

Beaumont New Ammonia: achieved first ammonia December 2025 Production of lower-carbon ammonia is conditional on supply of carbon abated hydrogen and ExxonMobil’s CCS facility becoming operational. Cost of production range is the average cost for Phase 1 over 2028 to 2030 during assumed steady state lower-carbon ammonia production excluding planned turnarounds. Assumes fixed/variable split of 70/30%, a range of Henry Hub pricing, and inclusion of 45Q tax credit. Project and commissioning activities will continue through early 2026 Handover of project expected in H1 2026 and production of lower-carbon ammonia targeted for H2 20261 Secured offtake agreements at prevailing market prices for traditional ammonia market Competitive unit cash cost of ~$290-320/tonne2 Beaumont New Ammonia, January 2026

Scarborough: 94% complete, on budget and on track1 As at 31 December 2025. Excludes Pluto Train 1 modifications. Completed drilling campaign for all eight development wells with reservoir quality in line with pre-drill expectations Floating production unit (FPU) arrived at Scarborough field in January 2026 and connected to the mooring chains Commissioned Integrated Remote Operations Centre at Woodside’s headquarters to facilitate remote operations Continued construction activities at Pluto Train 2, commencing commissioning of utility systems First LNG cargo targeted for Q4 2026 following completion of Pluto Train 2 construction and onshore and offshore commissioning activities Scarborough floating production unit

Trion: 50% complete, on budget and targeting first oil in 20281 As at 31 December 2025. Advanced FPU and floating storage and offloading facility (FSO) construction with the FPU hull nearing completion and first steel cut for FSO Granted regulatory approval of HSE management system, the final authorisation required to commence field activities Drilling expected to commence in early 2026 with all permits received On track for installation of FSO disconnectable turret mooring and facilities anchor piles in 2026 Progressing completion of SURF equipment for installation campaign in H2 2026 Lifting of first Trion module onto hull, February 2026

Woodside Louisiana LNG site Louisiana LNG: on budget and targeting first LNG in 2029 22% completion for total foundation project. Train completions as at 31 December 2025: Train 1 (28%), Train 2 (18%), Train 3 (13%). Woodside’s total capital expenditure for the Louisiana LNG Project is expected to be $9.9 billion against total project cost announced at FID of $17.5 billion. InfraCo = Louisiana LNG Infrastructure LLC. Hold Co = Louisiana LNG LLC. PipelineCo = Driftwood Pipeline LLC. Progressed construction to schedule under Bechtel EPC contract (22% complete)1 focusing on tank construction, marine infrastructure and piling Secured foundational transportation capacity for gas supply, providing access to diverse and abundant gas supply sources Completed sell-downs to strategic partners, with Woodside’s expected total capital expenditure now $9.9 billion (<60% of total capital expenditure)2 Stonepeak – divested 40% in InfraCo, funding 75% of capital expenditure in 2025 and 20263 Williams – divested 10% in HoldCo and 80% and operatorship of PipelineCo3 Continuing progress on further selldowns and offtake agreements

Underpinned by our focus and commitment to sustainability Net equity Scope 1 and 2 emissions, MtCO2-e Achieved 2025 net equity Scope 1 and 2 GHG emissions reduction target of 15% below starting base1 Zero high consequence injuries and reduction in process safety events Supported Indigenous-led nomination of UNESCO World Heritage listing of Murujuga Secured environmental approvals for NWS Project life extension1 and Trion Achieved 2025 net equity Scope 1 and 2 GHG emissions reduction target of 15% below starting base2 Reporting complies with new AASB S2 Climate-related Disclosures We invite you to join our upcoming Sustainability Investor Briefing on 16 March 2026 Federal Government approvals subject to conditions. Three separate legal proceedings have commenced in the Federal Court of Australia challenging the Federal Government's environmental approval, and one in the Western Australian Supreme Court challenging the State Government's environmental approval. Net equity Scope 1 and 2 GHG emissions reduction targets and aspiration are relative to a starting base of 6.27 Mt CO2-e which is representative of the gross annual average equity Scope 1 and 2 greenhouse gas emissions over 2016-2020 and which may be adjusted (up or down) for potential equity changes in producing or sanctioned assets with a final investment decision prior to 2021. Net equity emissions include the utilisation of carbon credits as offsets, inclusive of those required to meet regulatory obligations.

Oil: continued robust outlook Wood Mackenzie Macro Oils Investment Horizon Outlook (October 2025). Wood Mackenzie Macro Oil Investment Horizon Outlook (November 2025) and Wood Mackenzie Oil Supply Tool (Long Term H2 2025). Includes oil and NGLs. Oil demand is forecast to remain resilient as the world’s energy mix evolves1 Demand in hard-to-abate areas such as heavy transport and petrochemical sectors remains strong1 ~60% of near-term portfolio linked to oil supports revenue resilience across commodity cycles Global liquids supply and demand outlook2 MMbbl/d Onstream Under development Reserves growth Potential supply gap  Demand

LNG: robust outlook and ongoing sales 2025 2030 2035 2040+ JAPAN 0.4 Mtpa to JERA over 10 years KOREA 0.5 Mtpa to KOGAS for 10.5 years GERMANY/NETHERLANDS 0.8 Mtpa to UNIPER up to 2039 CHINA 0.6 Mtpa to China Resources for 15 years MALAYSIA 1.0 Mtpa to Petronas for 15 years TÜRKIYE ~0.5 Mtpa to BOTAŞ for 9 years GERMANY/NETHERLANDS (from LALNG) 1.0 Mtpa to UNIPER for 13 years Option for +10 years TAIWAN 0.6 Mtpa to CPC Taiwan over 10 years JAPAN 0.2 Mtpa to JERA over 5 years (winter demand) GERMANY/NETHERLANDS 1.0 Mtpa to UNIPER for 10 years KOREA 0.6 Mtpa to SK Gas for 13 years Recent contracting with end customers Signed in 2025 Forecast long-term structural demand growth for LNG supported by economic expansion in emerging Asian markets1 Periods of demand/supply imbalance are expected to be transitory compared to the forecast demand2 4.7 Mtpa signed in 2025, ~75% of Woodside’s LNG volumes contracted for 2026-2028 Resilience provided by diversity of start date, market and buyer Wood Mackenzie Global Gas 10-year investment horizon outlook (November 2025). Wood Mackenzie LNG Tool (January 2026). Asia Europe

World-class assets | Operational excellence | Project delivery | Trusted supplier | Financial discipline A business building resilience across cycles Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. Indicative, not guidance and as outlined on slides 9 and 16 in Woodside’s 2025 Capital Markets Day presentation, released 5 November 2025. Refer to slides 87-88 of the Capital Markets Day presentation for further details on the underlying assumptions. Consistent with 2025 Capital Markets Day, presented on a 3 year average for 2026-2028. Includes binding sales and purchases agreements only, Woodside’s equity share of Scarborough and Pluto LNG, Corpus Christi offtake volumes and assumes the Chevron asset swap is completed. Includes hedges for 10 MMboe placed during 2025 and 8 MMboe placed subsequent to the period. PRESENT $9.3 billion liquidity1 <1x net debt/EBITDA1 ~98% five-year average operated LNG reliability 82% cash margin average over last five years NEAR TERM <$34/bbl 2026-2027 average cash breakeven2 ~75% LNG volumes contracted for 2026-2028 ~30% gas hub indexation for 20263 18 MMboe hedged for 2026 at ~$70/bbl4 Staged delivery of major sanctioned projects increasing free cash flow Growing scale increases ability for value capture Diverse opportunity mix within portfolio Long-term structural demand 2030+ ~$9 billion Net operating cash flow in 20322 >300 MMboe Sales in 20322 Woodside’s competitive advantages

Graham Tiver EVP and Chief Financial Officer Capital management Maintaining disciplined capital allocation and strong balance sheet

Creating future value through disciplined capital management Consistent cost focus Disciplined cost management reducing unit production cost year-on-year Delivered over $200 million in cost reductions in 2025 Delivering maintenance campaigns on schedule and budget Driving structural cost reductions Disciplined investment decisions Opportunities must meet capital allocation framework Strategic partnering (e.g. Stonepeak, Williams) Portfolio rationalisation (e.g. Greater Angostura) Actively managed balance sheet Investment grade credit rating of Moody’s: Baa1 and S&P: BBB+1 Committed to shareholder returns with a track record of 80% payout ratio since 2013 Active risk management including hedging and liquidity management Corporate debt credit ratings. Baa1 by Moody’s, BBB+ by S&P Global. A credit rating is not a recommendation to buy, sell or hold securities and may be subject to revision or withdrawal at any time.

Capital management framework Excess cash Safe, reliable and low-cost operations Investment expenditure Strong balance sheet Dividend policy (minimum 50% payout ratio) Special dividends Share buy-backs Investment grade credit rating2 Maintain dividend based on NPAT excluding non-recurring items, targeting 50-80% payout ratio Targeting 10-20% gearing through the cycle Future investment Moody’s: Baa1 S&P: BBB+ 80% payout ratio 59 US cps 2025 full-year: 18.2% Operating cash flow Investing cash flow Full-year dividends Liquidity1 $7.2B $7.9B $9.3B $2.1B Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. Corporate debt credit ratings. Baa1 by Moody’s, BBB+ by S&P Global. A credit rating is not a recommendation to buy, sell or hold securities and may be subject to revision or withdrawal at any time. (Final dividend of $1.1B) ($5.3B when adjusted for NCI and lease repayments)

Outstanding EBITDA performance $9.3 billion EBITDA and >70% EBITDA margin underpinned by outstanding Sangomar production performance and consistent cost focus1 Strong EBITDA performance driven by increased production and high-quality asset base Marketing segment contribution of ~8% to EBIT1 Strong underlying NPAT of $2.6 billion despite lower average realised prices1 Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. EBITDA1 $ billion EBITDA margin EBITDA Pre-merger Post-merger

Strong balance sheet positioned to navigate volatility Liquidity of $9.3 billion supports capital commitments and shareholder returns1 Gearing of 18.2% within target range (10 – 20%) and net debt/EBITDA of 0.9x1 $2.3 billion received from Stonepeak and Williams on completion of Louisiana LNG sell-downs $34/bbl 2026-2027 average breakeven providing resilience2 Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. Indicative, not guidance and as outlined on slides 9 and 35 in Woodside’s 2025 Capital Markets Day presentation, released 5 November 2025. Refer to slides 87-88 of the Capital Markets Day presentation for further details on the underlying assumptions. Growth includes Sangomar Phase 1, Beaumont New Ammonia, Scarborough, Trion and Louisiana LNG. Liquidity $ billion Undrawn facilities Cash Base Capital Dividend Available cash Sources and uses, 2026-2032 ($ billion)2 Resilience at $55 Brent, $7 JKM Growth3

Delivering consistent, reliable returns Declared final dividend of $1.1 billion, 59 US cps fully franked Paying at the top end of dividend target range since 2013 Returned ~$11 billion (568 US cps) to shareholders since merger completion in 2022 while reinvesting in projects for future cash generation1 Strong underlying business enables continued ability to return value to shareholders Dividends returned since merger completion on 1 June 2022 to 2025 half-year. Excludes 2025 final dividend declared of $1.1 billion or 59 US cps. Strong dividends US cents per share Pre-merger Post-merger Interim dividend Final dividend BHP merger completion payment

Liz Westcott Acting Chief Executive Officer Close 2026: Continuing to execute strategy

Disciplined delivery focused on value Operate base business safely, reliably and efficiently Safely execute Pluto Train 1 major turnaround Layer sales and progress offtake Ramp-up Beaumont New Ammonia Deliver first LNG cargo from Scarborough Progress Louisiana LNG (including sell-downs) and Trion Progress strategic partnering opportunities Continue disciplined capital management Maintain strong liquidity through cost control and capital levers Actively refine portfolio for long-term value creation Maximise Deliver Create Full-Year 2025 Results Briefing Continue focus on sustainability and innovation

Q&A

Annexure

Why invest in Woodside 1 Woodside supplies energy to meet rising demand, enabling global growth, and assisting with customer decarbonisation goals 2 Woodside has a track record of generating durable, long-term cash flows and returning value to shareholders through the cycle 3 Woodside offers tangible growth catalysts through project start-ups and exposure to a high-quality cash-generative portfolio

Continued strong track record of safe and reliable operations Monetising through portfolio and marketing optimisation Major development projects focused on cost and schedule Strategic partnering and customer relationships Disciplined capital allocation and balance sheet management Actively refining the portfolio for long-term value creation Delivering our strategy Maximise performance from base business Deliver cash-generative assets Create future opportunities Full-Year 2025 Results Briefing Underpinned by a focus on sustainability and innovation

Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. Refer to slide 32 (NPAT reconciliation) of this presentation for the list of specific items for FY25. The calculation has been updated to adjust for contributions from/(to) NCI and lease repayments. The 2024 comparative has been restated to be presented on the same basis. Strong financial performance FY 2025 FY 2024 Change Operating revenue $m 12,984 13,179 1% EBITDA1 $m 9,277 9,276 0% EBIT1 $m 3,889 4,514 14% NPAT2 $m 2,718 3,573 24% Underlying NPAT1,2 $m 2,649 2,880 8% Operating cash flow $m 7,192 5,847 23% Free cash flow1,3 $m 1,889 (293) 745% Liquidity1 $m 9,262 6,723 38% Earnings per share US cps 143 189 24% Return on equity % 7.6 10.1 25% Full-year dividend US cps 112 122 8% Strong production supported performance despite lower average realised prices $9.3 billion liquidity enabling investments in near-term growth1 Delivering strong returns to shareholders and maintaining balance sheet flexibility

Net profit after tax reconciliation Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. Impact of lower realised prices offset by world-class Sangomar performance Pre-tax net hedge gains Pre-tax embedded derivative impact Pre-tax impairment on H2OK Project Adjusted for recognition of Louisiana LNG DTA and post-tax impairment on H2OK Project 1 REVENUE FROM THE SALE OF HYDROCARBONS COST OF SALES GENERAL, ADMINISTRATIVE, TAX AND OTHER FINAL DIVIDEND, FULLY FRANKED Fully franked final dividend of 59 US cps One-off transactions and tax impacts Full year of Sangomar depreciation Restoration provision updates primarily due to Stybarrow, Griffin and Minerva Recognition of Pluto PRRT DTA and Sangomar DTA in 2024 offset by recognition of Louisiana LNG DTA in 2025 Full year of Sangomar production primarily offset by lower NWS production Lower average realised prices Greater Angostura divestment

$ billion $ billion Five-year trends: key financial metrics Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. 2025 NPAT adjustments include the recognition of a Louisiana LNG DTA ($182 million) offset by H2OK Project impairment loss ($113 million). Revenue driven by outstanding performance at Sangomar, offset by lower prices and Greater Angostura divestment Consistent EBITDA performance, predominantly driven by strong production offsetting lower realised prices EBITDA1 Operating revenue Underlying NPAT1,2 $ billion

$ billion $ billion Five-year trends: cash flow 2022 investing cash flow includes GIP’s additional contribution to Pluto Train 2 ($0.8 billion) and cash received on the acquisition of BHP Petroleum ($1.1 billion). Without these items, 2022 investing cash flow would be $4.2 billion. 2024 investing cash flow includes the acquisitions of Beaumont New Ammonia ($1.9 billion) and Tellurian ($1.0 billion), post-acquisition spend on Louisiana LNG in 2024 ($0.2 billion) and proceeds of Scarborough sell-downs to LNG Japan and JERA Scarborough Pty Ltd ($2.3 billion). Without these items, investing cash flow would be $4.8 billion and free cash flow would be $0.6 billion. Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. The calculation has been updated to adjust for contributions from/(to) NCI and lease repayments. The prior year comparatives have been restated to be presented on the same basis. Investing cash flow1,2 Operating cash flow Free cash flow2,3,4 Benefit of GIP’s additional contribution to Pluto Train 2 Benefit from proceeds of Scarborough sell-downs Net impact of 2024 acquisitions and disposals $ billion Operating cash flow increased despite a lower price environment, driven by exceptional operational performance, Sangomar, and lower tax payments on lower prices Delivered positive free cash flow driven by strong operating cash flow and proceeds from Greater Angostura divestment, Williams and Stonepeak transactions Adjusted for contributions from NCI and lease repayments presented within financing cash flow NCI and lease repayments 2025 includes 100% of capital additions from Louisiana LNG with NCI contributions captured in free cash flow 2.6 (0.4) (0.4) (0.3) (0.4)

Resilient cash margin 80% cash margin in 2025 amid lower commodity prices1 Sustained cash margin of 80% for more than 5 years Non-IFRS financial measures. Refer to the glossary section of this presentation for the definition. Cash margin1 Cash margin (%) Cash margin Production costs Other cash costs

Actively managed debt portfolio Non-IFRS financial measure. Refer to the glossary section of this presentation for the definition. As at 31 December 2025. Continued access to debt markets, receiving strong support with $3.5 billion US bond issuance Executed a new $1.2 billion multi-tranche syndicated undrawn debt facility Portfolio weighted average term-to-maturity of 5.4 years Net debt1 Debt maturity profile1,2 $ billion $ billion

Strong contribution to global economies Based on the Australian Taxation Office’s 2023-2024 report of entity tax information released in October 2025 (data.gov.au/).​ Includes Trinidad and Tobago and Senegal production entitlements, which are paid in-kind. Excludes all Australian taxes.​ For the FY 2025 period. Determined by total tax expense, royalties, excise, levies and other taxes, divided by profit before such taxes, adjusted for one off items. The global all-in normalised effective tax rate decreases to 39% with one off items included. ​ Includes data relevant to the assets acquired through the merger with BHP’s petroleum business from 1 June 2022.​ Figures are reported on a cash basis (net of any refunds received, for example, refunds of tax overpaid in prior periods) and are rounded to the nearest million.​ ~A$2 billion in Australian taxes, royalties and levies paid in FY 2025 Largest payer of PRRT in Australia1 ~US$600 million of taxes, royalties and levies paid internationally in FY 20252 Global normalised all-in effective tax rate of 45%3 Australian tax contribution4,5 A$1,036m | Corporate income tax A$471m | PRRT A$230m | Federal royalties A$83m | Federal excise A$77m | Offshore petroleum levy A$72m Payroll tax and fringe benefits tax $ billion

Asset tables Asset Operating revenue $ million EBITDA1 $ million Depreciation and amortisation2 $ million EBIT1 $ million Capital expenditure1,3 $ million Production costs $ million Australia North West Shelf 1,554 1,287 571 716 214 175 Pluto 3,419 2,743 810 1,933 238 385 Wheatstone 748 603 354 249 209 70 Bass Strait 1,016 795 444 351 86 194 Macedon 202 162 63 99 8 32 Pyrenees 149 91 62 29 14 61 Ngujima-Yin 279 213 102 111 3 63 Okha 134 81 27 54 12 50 Scarborough - 23 5 18 1,421 - Other Australia - (442) - (442) 16 - Total Australia 7,501 5,556 2,438 3,118 2,221 1,030 Non-IFRS financial measures. Refer to the glossary section of this presentation for the definitions. Includes exploration permit cost amortisation, impairment losses and impairment reversals. Capital additions on property, plant and equipment, evaluation capitalised and other corporate spend. Excludes exploration capitalised and is presented net of capital contributions from non-controlling interests for the development of Louisiana LNG.

Asset tables Non-IFRS financial measures. Refer to the glossary section of this presentation for the definitions. Includes exploration permit cost amortisation, impairment losses and impairment reversals. Includes corporate, new energy projects that have not yet reached FID and other. Capital additions on property, plant and equipment, evaluation capitalised and other corporate spend. Excludes exploration capitalised and is presented net of capital contributions from non-controlling interests for the development of Louisiana LNG. Asset Operating revenue $ million EBITDA1 $ million Depreciation and amortisation2 $ million EBIT1 $ million Capital expenditure1,4 $ million Production costs $ million International Trinidad & Tobago 150 340 5 335 - 27 Atlantis 737 607 431 176 234 89 Shenzi 564 383 460 (77) 21 136 Mad Dog 660 570 289 281 239 59 Trion - (4) - (4) 884 - Sangomar 1,947 1,702 1,384 318 33 212 Louisiana LNG - 9 - 9 929 - Beaumont New Ammonia - (53) - (53) 22 - Other International 11 (127) 22 (149) 20 - Total International 4,069 3,427 2,591 836 2,382 523 Marketing 1,414 386 78 308 - - Corporate3 - (92) 281 (373) 100 - Total 12,984 9,277 5,388 3,889 4,703 1,553

Realised price Excludes any additional benefit attributed to produced LNG through third-party trading activities. Realised prices exclude the impact of periodic adjustments reflecting the arrangements governing Wheatstone LNG sales. The 2024 comparative has been restated to be presented on the same basis. TTF is converted from EUR/MWh to US$/MMBtu using published exchange rates and conversion factors. Products Units FY 2025 FY 2024 Variance LNG produced $/boe 62 66 (4) LNG traded1 $/boe 72 69 3 Pipeline gas $/boe 37 36 1 Oil and condensate $/boe 68 77 (9) NGLs $/boe 42 46 (4) Liquids traded $/boe 58 62 (4) Average realised price2 $/boe 60 63 (3) Average Dated Brent $/bbl 69 81 (12) WTI $/bbl 65 76 (11) JCC (lagged three months) $/bbl 76 88 (12) JKM $/MMBtu 13 12 1 TTF3 $/MMBtu 12 11 1 Henry Hub $/MMBtu 3 2 1

2026 full-year guidance Item Guidance Comments Volumes MMboe 172 – 186 Includes production volumes from hydrocarbons of 170 – 183 MMboe and Beaumont New Ammonia volumes of 2 – 3 MMboe. Pluto LNG train 1 major turnaround in Q2 2026, duration approximately 5 weeks. Gas hub exposure1 % ~ 30 Capital expenditure2,3 $ million 4,000 – 4,500 Consistent with past practice, guidance is at current Woodside equity interest. This excludes the impact of any subsequent sell-downs, future acquisitions or other equity changes. Excludes the final acquisition completion payment for Beaumont New Ammonia, expected in 2026. This will be separately disclosed in the cash flow statement. Abandonment expenditure $ million 500 – 800 Exploration expenditure $ million ~ 200 Production costs $ million 1,500 – 1,800 Feed gas, services and processing costs $ million 500 – 600 Includes Beaumont New Ammonia’s operating costs, in addition to the Group’s tolling costs, feed gas and processing costs. Property, plant and equipment depreciation and amortisation $ million 4,200 – 4,700 Consistent with 2025 Capital Markets Day, presented on a 3-year average for 2026-2028. Includes binding sales and purchases agreements only, Woodside’s equity share of Scarborough and Pluto LNG, Corpus Christ offtake volumes and assumes the Chevron asset swap is complete. Louisiana LNG (90% Louisiana LNG LLC, 60% Louisiana LNG Infrastructure LLC and 20% Driftwood Pipeline LLC) capital expenditure adjusted for the cash contributions from Stonepeak and WiIliams. Scarborough (74.9% participating interest), Pluto Train 2 (51% participating interest) and Trion (60% participating interest). Completion of the asset swap with Chevron assumed in H2 2026. Woodside’s equity interests at current participating interest prior to the completion for NWS Project, NWS Oil Project Wheatstone, Julimar-Brunello and Angel CCS assets.

Glossary $, $m, $B US dollar unless otherwise stated, millions of dollars, billions of dollars 1P Proved reserves AASB S2 Australian Accounting Standards Board S2 Climate-related Disclosures sets out disclosure requirements for an entity to provide useful information to primary users of its general purpose financial report about climate-related risks and opportunities that could reasonably be expected to affect the entity’s cash flows, access to finance or cost of capital over the short, medium or long term. Abate/abatement Avoidance, reduction or removal of an amount of carbon dioxide or equivalent Aspiration Woodside uses this term to describe an aspiration to seek the achievement of an outcome but where achievement of the outcome is subject to material uncertainties and contingencies such that Woodside considers there is not yet a suitable defined plan or pathway to achieve that outcome Average realised price Revenue from sale of hydrocarbons ($ million) divided by sales volume (MMboe) A$, AUD Australian dollars Bbl Barrels Bcf Billion cubic feet Board The Board of Directors of Woodside Energy Group Ltd Breakeven Breakeven is calculated on an adjusted free cash flow basis. It excludes capital and selldown proceeds from major projects (Louisiana LNG, Scarborough, Trion, and Beaumont New Ammonia), marketing, exploration and hedging Brent Intercontinental Exchange (ICE) Brent Crude deliverable futures contract (oil price) boe, kboe, MMboe, Bboe Barrel of oil equivalent, thousand barrels of oil equivalent, million barrels of oil equivalent, billion barrels of oil equivalent CAGR Compound annual growth rate Capital expenditure Capital additions on property, plant and equipment, evaluation capitalised and other corporate spend. Excludes exploration capitalised and adjusted for the capital contribution from its non‑controlling interests for the development of Louisiana LNG Capital expenditure excluding Louisiana LNG Capital additions on property, plant and equipment, evaluation capitalised and other corporate spend. Excludes exploration capitalised and net capital additions on Louisiana LNG Carbon credit A tradable financial instrument that is issued by a carbon-crediting program. A carbon credit represents a greenhouse gas emission reduction to, or removal from, the atmosphere equivalent to 1 tCO2-e, calculated as the difference in emissions from a baseline scenario to a project scenario. Carbon credits are uniquely serialised, issued, tracked and retired or administratively cancelled by means of an electronic registry operated by an administrative body, such as a carbon-crediting program Cash margin Gross profit/loss adjusted for other cost of sales, trading costs, oil and gas properties depreciation and amortisation and other revenue. Excludes the marketing segment. Cash margin % is calculated as cash margin divided by revenue from sale of hydrocarbons (excluding marketing segment) CBAM Carbon border adjustment mechanism CCS Carbon capture and storage CCUS Carbon capture utilisation and storage CO2 Carbon dioxide CO2-e CO₂ equivalent. The universal unit of measurement to indicate the global warming potential of each of the seven greenhouse gases, expressed in terms of the global warming potential of one unit of carbon dioxide. It is used to evaluate releasing (or avoiding releasing) any greenhouse gas against a common basis1 Condensate Hydrocarbons that are gaseous in a reservoir but that condense to form liquids as they rise to the surface cps Cents per share Decarbonisation Woodside uses this term to describe activities or pathways that have the effect of moving towards a state that is lower-carbon, as defined in this glossary DES Delivery ex ship DTA Deferred tax asset EBIT Calculated as a profit before income tax, PRRT and net finance costs EBITDA Calculated as profit before income tax, PRRT, net finance costs, depreciation and amortisation, impairment losses, impairment reversals EBITDA margin EBITDA margin % is calculated as EBITDA divided by operating revenue Emissions Emissions refers to emissions of greenhouse gases unless otherwise stated EPC Engineering, procurement and construction EPS Earnings per share Equity greenhouse gas emissions Woodside sets its Scope 1 and 2 greenhouse gas emissions reduction targets on an equity basis. This ensures that the scope of its emissions reduction targets is aligned with its economic interest in its investments. Equity emissions reflect the greenhouse gas emissions from operations according to Woodside’s share of equity in the operation. Its equity share of an operation reflects its economic interest in the operation, which is the extent of rights it has to the risks and rewards flowing from the operation2 Exploration expenditure Includes exploration and evaluation expenditure less amortisation of licence acquisition costs and prior year exploration expense written off FEED Front-end engineering design FID Final investment decision FOB Free on board FPSO Floating production storage and offloading FPU Floating production unit Free cash flow Net cash flow from/(used in) operating activities and net cash flow from/(used in) investing activities, adjusted for capital contributions from/(to) non-controlling interests and lease repayments FSO Floating storage and offloading facility See IFRS Foundation 2021: Climate Related Disclosures Prototype. Appendix A. World Resources Institute and World Business Council for Sustainable Development, 2004. “GHG Protocol: a corporate accounting and reporting standard” https://www.wbcsd.org/Programs/Climate-and-Energy/Climate/Resources/A-corporate-reporting-and-accounting-standard-revised-edition.

Glossary See IFRS Foundation 2021: Climate Related Disclosures Prototype. Appendix A. IOGP Fatality and Permanent Impairment injury definitions | IOGP. Australian Clean Energy Regulator, 2023. “Corporate Emissions Reduction Transparency report 2023” https://cer.gov.au/markets/reports-and-data/corporate-emissions-reduction-transparency-report/corporate-emissions-reduction-transparency-report-2023/cert-report-2023-glossary. IPCC, 2018: Annex I: Glossary [Matthews, J.B.R. (ed.)]. In: Global Warming of 1.5°C. An IPCC Special Report on the impacts of global warming of 1.5°C above pre-industrial levels and related global greenhouse gas emission pathways, in the context of strengthening the global response to the threat of climate change, sustainable development, and efforts to eradicate poverty [Masson-Delmotte, V., P. Zhai, H.-O. Pörtner, D. Roberts, J. Skea, P.R. Shukla, A. Pirani, W. Moufouma-Okia, C. Péan, R. Pidcock, S. Connors, J.B.R. Matthews, Y. Chen, X. Zhou, M.I. Gomis, E. Lonnoy, T. Maycock, M. Tignor, and T. Waterfield (eds.)]. Cambridge University Press, Cambridge, UK and New York, NY, USA, pp. 541–562. https://doi.org/10.1017/9781009157940.008. Gearing Net debt divided by net debt and equity attributable to the equity holders of the parent GHG or greenhouse gas The seven greenhouse gases listed in the Kyoto Protocol are: carbon dioxide (CO2); methane (CH4); nitrous oxide (N2O); hydrofluorocarbons (HFCs); nitrogen trifluoride (NF3); perfluorocarbons (PFCs); and sulphur hexafluoride (SF6)1 Goal Woodside uses this term to broadly encompass its targets and aspirations High Consequence Injury or HCI A high-consequence injury is a work-related injury that results in a fatality or permanent impairment injury2 Woodside’s definition for HCI has changed in 2025 to align with the IOGP Fatality and Permanent Impairment definition. This definition was adopted to focus attention on the highest risks to people. In the previous reporting period, the HCI definition included long-term disabling injuries (i.e where the person will make a full recovery, but recovery exceeds 180 days) in HCI statistics which focused disproportionate effort towards injury management, access to treatment and privacy issues HSE Health, safety and environment IFRS International Financial Reporting Standards Investing cash flow Cash flow from investing activities IRR or Internal rate of return Internal rate of return. IRR is calculated as the rate of return required for Woodside’s share of after-tax project cashflows that deliver an NPV of zero JCC The Japan customs-cleared crude is the average price of customs-cleared crude oil imports into Japan as reported in customs statistics (also known as ‘Japanese crude cocktail’) and is used as a reference price for long-term supply LNG contracts JKM Japan Korea Marker is the North-east Asian spot price index for LNG delivered ex-ship to Japan, South Korea, China and Taiwan JV Joint venture KGP Karratha Gas Plant Liquidity Total cash and cash equivalents and available undrawn debt facilities LNG Liquefied natural gas Lower-carbon Woodside uses this term to describe the characteristic of having lower levels of associated potential GHG emissions when compared to historical and/or current conventions or analogues, for example relating to an otherwise similar resource, process, production facility, product or service, or activity. When applied to Woodside’s strategy, please see the definition of lower-carbon portfolio Lower-carbon ammonia Lower-carbon ammonia is characterized here by the use of hydrogen with emissions abated by carbon capture and storage (CCS), with an expected ammonia lifecycle (Scope 1, 2 and 3) carbon emissions intensity of 0.8 tCO2/tNH3 (based on contracted intensity threshold with Linde) relative to unabated ammonia with a lifecycle (Scope 1, 2 and 3) carbon emissions intensity of 2.3 tCO2/tNH3 (Hydrogen Europe, 2023) Lower-carbon portfolio For Woodside, a lower-carbon portfolio is one from which the net equity Scope 1 and 2 greenhouse gas emissions, which includes the use of offsets, are being reduced towards targets, and into which new energy products and lower-carbon services are planned to be introduced as a complement to existing and new investments in oil and gas. Our Climate Policy sets out the principles that we believe will assist us achieve this aim Lower-carbon services Woodside uses this term to describe technologies, such as CCUS or offsets that could be used by customers to reduce their net greenhouse gas emissions MMbbl Million barrels MMBtu Million British thermal units Mtpa, mmtpa Million tonnes per annum MWh Megawatt hour Net debt Interest-bearing liabilities and lease liabilities less cash and cash equivalents Net equity greenhouse gas emissions Woodside’s equity share of net greenhouse gas emissions which includes the utilisation of carbon credits as offsets Net greenhouse gas emissions Woodside has set its Scope 1 and 2 greenhouse gas emissions reduction targets on a net basis, allowing for both direct emissions reductions from its operations and emissions reduction achieved from the utilisation of carbon credits as offsets (including credits relating to avoidance, reduction and/or removal activities). Net greenhouse gas emissions are equal to an entity’s gross greenhouse gas emissions reduced by the number of retired carbon credits3 Net operating cash flow Net cash from operating activities adjusted to remove non-controlling interest to present net cash attributable to Woodside (i.e. not on a consolidated basis) and the impact of lease repayments. Net zero Net zero emissions are achieved when anthropogenic emissions of greenhouse gases to the atmosphere are balanced by anthropogenic removals over a specified period. Where multiple greenhouse gases are involved, the quantification of net zero emissions depends on the climate metric chosen to compare emissions of different gases (such as global warming potential, global temperature change potential, and others, as well as the chosen time horizon)4 New energy Woodside uses this term to describe energy technologies, such as hydrogen or ammonia, that are emerging in scale but which are expected to grow during the energy transition due to having lower greenhouse gas emissions at the point of use than conventional fossil fuels NGLs Natural gas liquids NPAT Net profit after tax NWS North West Shelf OECD Organisation for Economic Cooperation and Development Offsets The compensation for an entity’s greenhouse gas emissions within its scope by achieving an equivalent amount of emission reductions or removals outside the boundary or value chain of that entity

Glossary See the IOGP Fatality and Permanent Impairment injury definitions. https://www.iogp.org/workstreams/safety/safety/iogp-fatality-and-permanent-impairment/iogp-fatality-and-permanent-impairment-injury-definitions/. See IFRS Foundation 2021: Climate Related Disclosures Prototype. Appendix A. Operating cash flow Cash flow from operating activities Operator, Operated and non-operated Oil and gas joint venture participants will typically appoint one company as the operator, which will hold the contractual authority to manage joint venture activities on behalf of the joint venture participants. Where Woodside is the operator of a joint venture in which it holds an equity share, this report refers to that joint venture as being operated. Where another company is the operator of a joint venture in which Woodside holds an equity share, this report refers to that joint venture as being non-operated Other cash cost margin Other cash costs include royalties, excise and levies, insurance, inventory movement, shipping and direct sales costs and other hydrocarbon costs. Excludes the marketing segment. Other cash cost margin % is calculated as other cash costs divided by revenue from sale of hydrocarbons (excluding marketing segment) Permanent Impairment Injury A permanent impairment is defined as the outcome of a work-related2 injury from which the worker cannot or is not expected to return to their previous (pre-incident) whole person function as a result of an acute, single incident, resulting in any of the following :permanent loss of body parts  permanent reduction of organ's physiological function permanent reduction in skin and musculoskeletal function1 PJ Petajoules PRRT Petroleum resource rent tax Process safety event (Tier 1 and Tier 2) An unplanned or uncontrolled loss of primary containment (LOPC) of any material including non-toxic and nonflammable materials from a process, or an undesired event or condition. Process safety events are classified as Tier 1 – LOPC of greatest consequence or Tier 2 – LOPC of lesser consequence. As defined by American Petroleum Institute (API) recommended practice 754 Primary energy consumption The total energy consumption of a country, encompassing the energy used by the energy sector itself, energy transformation and distribution losses, and final consumption by end-users Return on equity Annualised net profit after tax attributable to equity holder of the parent divided by equity attributable to equity holders of the parent RFSU Ready for start-up Scope 1 greenhouse gas emissions Direct greenhouse gas emissions. These occur from sources that are owned or controlled by the company, for example, emissions from combustion in owned or controlled boilers, furnaces, vehicles, etc., emissions from chemical production in owned or controlled process equipment. Woodside estimates greenhouse gas emissions, energy values and global warming potentials are estimated in accordance with the relevant reporting regulations in the jurisdiction where the emissions occur (e.g. Australian national Greenhouse and Energy Reporting (nGER), US EPA Greenhouse Gas Reporting Program (GHGRP)). Australian regulatory reporting principles have been used for emissions in jurisdictions where regulations do not yet exist2 Scope 3 greenhouse gas emissions Other indirect greenhouse gas emissions. Scope 3 is a reporting category that allows for the treatment of all other indirect emissions. Scope 3 emissions are a consequence of the activities of the company but occur from sources not owned or controlled by the company. Some examples of Scope 3 activities are extraction and production of purchased materials; transportation of purchased fuels; and use of sold products and services. Please refer to the data table on page 72 of the Climate Transition Action Plan and 2023 Progress Report for further information on the Scope 3 emissions categories reported by Woodside2 Starting base The starting base has been adjusted for the merger between Woodside and BHP Group’s Petroleum business (completed on 1 June 2022) which increased the starting base from 3.59 Mt CO₂‑e to 6.32 Mt CO₂‑e and for the divestment of the Greater Angostura assets (completed on 11 July 2025) which subsequently reduced it from 6.32 Mt CO₂‑e to 6.27 Mt CO₂‑e SURF Subsea, umbilicals, risers and flowlines Sustainability (including sustainable and sustainably) References to sustainability (including sustainable and sustainably) are used with reference to Woodside’s Sustainability Committee and sustainability related Board policies, as well as in the context of Woodside’s aim to ensure its business is sustainable from a long-term perspective, considering a range of factors including economic (including being able to sustain our business in the long term by being low cost and profitable), environmental (including considering our environmental impact and striving for a lower-carbon portfolio), social (including supporting our license to operate), and regulatory (including ongoing compliance with relevant legal obligations). Use of the terms ‘sustainability’, ‘sustainable’ and ‘sustainably’ is not intended to imply that Woodside will have no adverse impact on the economy, environment, or society, or that Woodside will achieve any particular economic, environmental, or social outcomes Target Woodside uses this term to describe an intention to seek the achievement of an outcome, where Woodside considers that it has developed a suitably defined plan or pathway to achieve that outcome Tier 1 process safety event A typical Tier 1 process safety event is loss of containment of hydrocarbons greater than 500 kg (in any one-hour period) Tier 2 process safety event A typical Tier 2 process safety event is loss of containment of hydrocarbons greater than 50 kg but less than 500 kg (in any one-hour period) TJ/day Terajoules per day TTF Title transfer facility Underlying NPAT Net profit after tax from the Group’s operations excluding any exceptional items Unit production cost or UPC Production costs ($ million) divided by production volume (MMboe) US, USA United States of America USD United States dollar Woodside Woodside Energy Group Ltd ACN 004 898 962 or its applicable subsidiaries

Full-Year 2025 Results Briefing