Earnings release
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THIRD QUARTER REPORT FOR PERIOD ENDED 30 SEPTEMBER 2026 ASX: WDS | NYSE: WDS Wednesday, 21 October 2026 Strong performance from improved production and pricing Performance highlights • Achieved $84/boe realised LNG price during Q3 2026, an increase of 27% compared to Q2 2026 reflecting price lags from Q2 2026, realised values from LNG portfolio optimisation undertaken in Q2 2026 and stronger gas hub market pricing. • Delivered quarterly operating revenue of $4,281 million, up 2% on Q2 2026 from strong LNG performance offset by lower average realised pricing from the liquids portfolio. • Delivered quarterly production volumes of 46.2 MMboe (503 Mboe/d), up 12% from Q2 2026 reflecting higher production from Pluto LNG following turnaround and maintenance activities completed in Q2 2026. • Achieved operational reliability of greater than 99% at Sangomar, NWS Project LNG and Pluto LNG. • Completed NWS single train planned major turnaround campaign on schedule and budget. Project highlights • The Scarborough Energy Project was 99% complete and remains on budget and on track for first LNG cargo this year. • The Trion Project was 71% complete at quarter end and remains on budget, with floating production unit (FPU) fabrication advancing to 96% completion, targeting first oil in 2028. • The Louisiana LNG Project remains on budget, targeting first LNG in 2029. It is 32% complete with Train 1 41% complete. Business and portfolio highlights • Entered into an agreement to sell Woodside’s 70% operated interest in the Calypso Project to bp. • Completed the strategic review of Beaumont New Ammonia (BNA) and will initiate a formal process to reduce Woodside’s investment and achieve value for shareholders. 2026 full-year guidance Prior Current Comment Total production volumes1 MMboe 174—185 174—181 • Beaumont New Ammonia volumes revised to 1.5-2.5 MMboe • Narrowing of window for Scarborough first LNG cargo • Reduced production at Okha FPSO • Completion of start-up and performance testing of Julimar Development Phase 3 in September Gas hub exposure2 % ~30 No change Capital expenditure3 $ million 4,000—4,500 No change Abandonment expenditure $ million 500—800 No change Exploration expenditure $ million ~200 No change Production costs $ million 1,500—1,800 No change Feed gas, services and processing costs $ million 500—600 No change Property, plant and equipment depreciation and amortisation $ million 4,200—4,700 No change 1 | Third quarter report for period ended 30 September 2026 1 Total production volumes includes 1.5—2.5 MMboe from Beaumont New Ammonia (prior guidance included 2—3 MMboe). 2 Gas hub indices include Japan Korea Marker (JKM), Title Transfer Facility (TTF) and National Balancing Point. It excludes Henry Hub. 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. 3 Capital expenditure is reported on the basis of Woodside’s net ownership interests for each project as at 30 September 2026. 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 Wallaby I Acquiror LP (Stonepeak) and Williams Louisiana LNG LLC (Williams). Scarborough (74.9% participating interest) and Pluto Train 2 (51% participating interest). Trion (60% participating interest). Excludes the final acquisition completion payment for Beaumont New Ammonia of $470 million. Completion of the asset swap with Chevron assumed to occur in Q4 2026.
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Woodside CEO Liz Westcott said the strong third quarter performance reflected the company’s highly reliable operations and disciplined execution of major growth projects. “Amid ongoing volatility in global energy markets, we have remained a reliable supplier to our customers. Increased quarterly operating revenue reflected increased production and strong realised prices. “We delivered quarterly production of 46.2 million barrels of oil equivalent, up 12% from the previous quarter following the successful completion of the Pluto LNG turnaround in the second quarter and the NWS turnaround in the third quarter. “We maintained outstanding reliability across our global portfolio, with reliability of 99.8% at Pluto LNG and 99.3% at the NWS Project in Australia, and 99.2% at Sangomar in Senegal. “We recorded three process safety events during the quarter. Safety remains our highest priority and we are focused on applying the lessons learned from these incidents and strengthening our controls in this vitally important area. “We continued executing our major growth projects to budget and schedule. The Scarborough Energy Project is now 99% complete, with gas from the Scarborough reservoir introduced into the FPU and exported into the trunkline during the quarter. We remain on track for first LNG cargo this year. “The Trion Project is now 71% complete and targeting first oil in 2028. Fabrication of the FPU is well advanced, with integration and pre-commissioning activities underway. “Louisiana LNG is targeting first LNG in 2029, with construction progressing across all three trains and the project 32% complete. “We continued to optimise our portfolio through the ongoing integration of the Gippsland Basin assets and divestment of our operated interest in the Calypso Project. Following completion of the Beaumont New Ammonia strategic review, we will now initiate a formal process to reduce our investment and achieve value for our shareholders. These actions demonstrate our disciplined approach to portfolio management and capital allocation, with a clear focus on investments that deliver long-term shareholder value. “We remain committed to supplying Australia’s domestic gas market and are assessing our plans for four proposed development wells in the Bass Strait. Development will depend on technical assessments and the implications of the Federal Government’s domestic gas reservation scheme.” 2 | Third quarter report for period ended 30 September 2026
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Comparative performance at a glance Q3 2026 Q2 2026 Change % Q3 2025 Change % YTD 2026 YTD 2025 Change % Operating revenue $ million 4,281 4,185 2% 3,359 27% 11,727 9,949 18% Production volumes4 MMboe 46.2 41.3 12% 50.8 (9%) 132.7 149.9 (11%) Gas MMscf/d 1,697 1,326 28% 1,827 (7%) 1,534 1,831 (16%) Liquids Mbbl/d 202 214 (6%) 231 (13%) 212 228 (7%) Ammonia kT/d 0.8 1.8 (56%) — —% 1.3 — —% Total Mboe/d 503 454 11% 552 (9%) 486 549 (11%) Sales volumes5 MMboe 51.1 48.0 6% 55.1 (7%) 150.9 159.9 (6%) Gas MMscf/d 2,043 1,672 22% 2,122 (4%) 1,910 2,049 (7%) Liquids Mbbl/d 193 227 (15%) 226 (15%) 213 226 (6%) Ammonia kT/d 1.0 2.1 (52%) — —% 1.3 — —% Total Mboe/d 555 528 5% 599 (7%) 553 586 (6%) Average realised price $/boe 84 85 (1%) 60 40% 77 61 26% Capital expenditure and acquisitions $ million 722 784 (8%) 1,323 (45%) 2,829 3,881 (27%) Capital expenditure6 $ million 722 784 (8%) 1,323 (45%) 2,359 3,881 (39%) Acquisitions $ million — — —% — —% 470 — —% Operations Pluto LNG • Achieved quarterly LNG reliability of 99.8%. • Preparation for the subsea tie-in and commissioning of the XNA-03 infill well continued ahead of targeted start-up in Q4 2026. North West Shelf Project • Achieved quarterly LNG reliability of 99.3%. • Completed single LNG train planned turnaround campaign in September 2026 on budget and schedule. • Hearings on three legal proceedings in the Federal Court of Australia associated with the NWS Project Extension Commonwealth environmental approvals were held in July 2026, with the decisions reserved. A separate proceeding concerning the State environmental approval remains before the Supreme Court of Western Australia, with a hearing scheduled for Q4 2026. • The NWS Project is continuing with infrastructure retirement planning at Karratha Gas Plant (KGP) while maintaining the capacity to provide processing services for third-party gas. Planning is underway to retire a second LNG train in 2027 subject to relevant approvals. Wheatstone and Julimar-Brunello • Progressed towards asset swap transaction completion, including the satisfaction of certain conditions precedent relating to the following: ◦ Completion of the Julimar Development Phase 3 project, with start-up and performance testing of the final development wells completed in September 2026. ◦ Completion of decommissioning of three Julimar-Brunello exploration wells, and wellhead severance of a further two previously-abandoned exploration wells. • Subject to the receipt of all regulatory approvals, the asset swap transaction continues to target completion in Q4 2026.7 3 | Third quarter report for period ended 30 September 2026 4 Percent change in total production may differ from percent change in daily production due to the number of days in each quarter. 5 Restated additional volumes of 0.09 MMboe in Q3 2025 and 0.28 MMboe in YTD 2025 to reflect a revised MMBtu to boe conversion factor. 6 Louisiana LNG YTD 2026 project spend includes $185 million of prepayments recognised in investing cash flow that are recoverable through partner cash calls but are not yet recognised as capital expenditure. 7 Completion of the transaction is subject to the remaining conditions precedent. See “Woodside simplifies portfolio and unlocks long-term value” announced on 19 December 2024.
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Bass Strait • Achieved quarterly reliability of 91%. • Achieved completion of the five Turrum Phase 3 Project development wells with first production targeting H1 2027. • Progressed integration of the Gippsland Basin assets into Woodside’s operated portfolio following transfer of operatorship from ExxonMobil on 1 July 2026. Other Australia • Following remediation of a subsea mooring system defect and successful FPSO reconnection, production resumed at Okha, with ongoing well assessment supporting further production restoration. • Subsequent to the period, the Pyrenees floating production storage and offloading (FPSO) disconnected ahead of scheduled shipyard activity in Q4 2026. Sangomar • Achieved an average daily production rate of 94 Mbbl/d (100% basis, 73 Mbbl/d Woodside share) with reliability of 99.2%. • Production rate reflects natural field decline and reduced production sharing contract (PSC) net entitlement following recovery of 100% Woodside-funded pre-FID costs. Gulf of America • Achieved quarterly reliability of 94.3% at Shenzi. • Executed a planned shutdown at Shenzi in July 2026 and a three-well intervention campaign in August 2026. • Atlantis achieved start-up of the Major Facility Expansion (MFX) project, bringing the first of two water injectors online. The project added subsea infrastructure, wells and upgraded water injection equipment. Beaumont New Ammonia • BNA suspended operations for approximately 30 days following a Tier 1 process safety event. There were no injuries to personnel or damage to equipment and no lasting impact to the environment. The facility was safely restarted following completion of an internal investigation and implementation of appropriate actions. • Production during the quarter was constrained to 69% of nameplate capacity due to third-party feedstock availability and the 30 day shut down. Third-party cargoes were sourced to satisfy customer commitments on similar financial terms. • Commencement of lower-carbon ammonia production remains targeted for 2027, subject to commissioning of Linde’s low-carbon hydrogen facilities and start-up of ExxonMobil’s carbon capture and storage (CCS) infrastructure. During the quarter, the Texas Railroad Commission voted to approve the permit for ExxonMobil’s Rose carbon storage project, moving it into the final stages of a multi-year regulatory process. • Completed the strategic review of BNA. In light of the evolving pace of lower-carbon ammonia market development, Woodside will initiate a formal process to reduce its investment in BNA investment and achieve value for shareholders. Marketing Revenue and trading • Strong marketing performance reflected the realisation of value from LNG portfolio optimisation undertaken in Q2 2026, with revenue recognised as cargoes were delivered in Q3 2026. • Average realised LNG prices improved quarter-on-quarter, reflecting the realisation of price lags from Q2 2026 and stronger gas hub market pricing in the lead up to northern hemisphere winter months. • Approximately 33% of LNG sold was linked to gas hub indices during the quarter. • The impact of crude supply disruptions softened during the quarter as export flows recovered and market balances improved, resulting in lower market prices for crude oil and weaker realised premiums for the liquids portfolio (oil, condensate and liquids traded). Pipeline gas • Executed incremental pipeline gas sales of: 4 | Third quarter report for period ended 30 September 2026
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◦ 12.9 PJ to be delivered to the Western Australian market from 2027 to 2029 ◦ 18.4 PJ to be delivered to the East Coast market from 2026 to 2028. • Progressed expression of interest for 20 PJ of Bass Strait supply and finalised a number of 2027 and 2028 offers during the period. Projects Scarborough Energy Project • The Scarborough and Pluto Train 2 projects remain on budget and were 99% complete at the end of the quarter (excluding Pluto Train 1 modifications). • The FPU and subsea production system commissioning and start-up activities continued, including well clean-up and export of gas to pressurise the trunkline. Well clean-up results are in line with reservoir and well performance expectations. • Completed all mechanical runs of Pluto Train 2 compressors and, subsequent to the period, Scarborough gas was introduced to the warm end (gas pre-treatment) of the LNG train. Activities in the cold end continue to progress, which will enable the commencement of gas liquefaction. • Following the Pluto Train 1 planned major maintenance campaign in Q2, modifications to Pluto Train 1 which will allow processing of Scarborough gas continued. The final module arrived onsite with activities focused on module hook-up and integration. • First LNG cargo is on track for Q4 2026. Trion • The Trion Project remains on budget and was 71% complete at the end of the quarter. • Advanced the drilling campaign, with 10 of 24 wells drilled and the first subsea tree installed. • Delivered subsea equipment and disconnectable turret mooring (DTM) buoy to Mexico and commenced offshore installation. • The FPU fabrication reached 96% completion, with integration and pre-commissioning activities underway. • Progressed floating storage and offloading vessel construction, including completion of DTM turret integration into the hull. • The project is targeting first oil in 2028. Louisiana LNG • The Louisiana LNG Project remains on budget and was 32% complete at the end of the quarter. • LNG terminal construction advanced across marine, site works and LNG tanks, with LNG Tank 1 wall concrete reaching 50% completion. • Train 1 was 41% complete at the end of the quarter, with structural steel and above-ground piping installation progressed. • Trains 2 and 3 were 27% and 22% complete respectively at the end of the quarter, with above-ground piping installation commenced for Train 2 and first concrete foundation poured for Train 3. • Structural steel supply challenges associated with ongoing disruptions in the Middle East continue to be mitigated through alternative logistics routes and fabrication sources. • Ongoing engagement with high-quality counterparties for equity participation and LNG offtake continues. • The project is targeting first LNG in 2029. Hydrogen Refueller @H2Perth • Ready for start-up was achieved and commissioning activities continued onsite with first hydrogen production targeting Q4 2026.8 Decommissioning • Completed the plug and abandonment (P&A) of five wells in the Julimar-Brunello and NWS gas fields. • Commenced offshore wellhead severance across the NWS gas, NWS oil and Julimar-Brunello fields, with nine wellheads removed. 5 | Third quarter report for period ended 30 September 2026 8 The project has received funding from the Hydrogen Fuelled Transport Project Funding Process as part of the Western Australian Government’s Renewable Hydrogen Strategy.
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• Continued progress across the Gippsland Basin Joint Venture wells P&A campaign, including conductor recovery activities at the Cobia field, completion of preparatory work for the Snapper campaign and commencement of the Barracouta A P&A campaign. • Progressed execution readiness for the offshore Echo Yodel pipeline removal campaign. • Submitted and secured NOPSEMA acceptance of Enfield decommissioning project close-out documentation. Development and exploration Browse • The Browse to North West Shelf Project continues to advance technical definition, regulatory approvals and commercial agreements as part of pre-front end engineering design activities. • Continued engagement with regulators to progress environmental approvals. Following submission of the revised Environmental Protection and Biodiversity Conservation Act 1999 referral, the Commonwealth regulator has determined that the Browse Carbon Capture and Storage (CCS) Project will be assessed by Environmental Impact Statement. • Progressed market engagement for the design and construction of the FPSO facilities and engineering studies of downstream modifications required for processing Browse gas at Karratha Gas Plant. Sunrise • The Sunrise Joint Venture reached alignment with the Governments of Timor-Leste and Australia on the key principles underpinning a new Greater Sunrise PSC and associated fiscal framework. • The terms of the existing PSCs (JPDA PSC 03-19 and JPDA PSC 03-20) were extended to 31 March 2027 to facilitate implementation of the new PSC arrangements. Calypso • On 6 August 2026, Woodside entered an agreement to sell its 70% operated interest in the Calypso Project to bp.9 • All key conditions precedent have now been met, with completion of the transaction targeting Q4 2026. Exploration • The Nasim-1X well, operated by ENI, was spud on the Tiba license in Egypt in August 2026 and drilling activities are ongoing. Woodside holds a 40% non-operated interest. • Woodside was awarded one lease in the US Gulf of America where Woodside was the successful bidder from the Big Beautiful Gulf 3 Lease Sale held in August 2026. • E n t e r e d a n o n - b i n d i n g m e m o r a n d u m o f u n d e r s t a n d i n g w i t h P e t r ό l e o s M e x i c a n o s ( P E M E X ) to evaluate deepwater opportunities in the Gulf of Mexico. Corporate activities Cost reduction • Woodside continued to progress the cost reduction program during the quarter, focused on improving efficiency and productivity. • Initiatives underway include simplifying organisational structures, improving maintenance and contracting processes, and expanding the use of automation and AI. • The program is targeting to deliver a US$350 million structurally lower recurring cost base against the 2025 baseline from 2028. Climate and sustainability • Three process safety events were recorded during the quarter. ◦ A Tier 1 event at BNA (refer to the BNA section for details). ◦ Two Tier 2 events involving: ◦ a marine diesel oil release during flushing operations at Okha, which had no environmental impact as the release was contained. ◦ a methane release from pipework during turnaround activities at KGP. 6 | Third quarter report for period ended 30 September 2026 9 Completion of the transaction is subject to the remaining conditions precedent. See “Woodside rationalises global portfolio with Calypso divestment”.
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• The Sam Houston Jones State Park Project, a voluntary environmental and biodiversity restoration initiative located 15 miles from LALNG, has progressed, with approximately 50% of site preparation completed ahead of seedling planting. Hedging • As at 30 September 2026, approximately 87% of the 30 MMboe of 2026 oil-linked production previously hedged (at an average price of $74.23 per barrel) had been cash settled. No additional oil-linked corporate hedges were entered during the quarter and the 2027 hedge position of 10 MMboe remains unchanged. • Continued to utilise Henry Hub and TTF commodity swaps in connection with overall management of Corpus Christi LNG volumes. • For 2026 year to date, hedge settlements resulted in a net cash outflow of approximately $565 million, and a reduction to pre-tax profit of $519 million. Cash settlements on oil-linked hedges occur in advance of the related profit and loss impact, resulting in temporary differences. Embedded commodity derivative • In 2023, Woodside entered a revised long-term gas sale and purchase contract with Perdaman. A component of the selling price is linked to the price of urea, creating an embedded commodity derivative in the contract. The fair value of the embedded derivative is estimated using a Monte Carlo simulation model. • As there is no long-term urea forward curve, TTF continues to be used as a proxy to simulate the value of the derivative over the life of the contract. • For 2026 year to date, an unrealised pre-tax loss of approximately $179 million is expected to be recognised through other expense. Funding and liquidity • During the quarter Woodside paid a fully franked dividend of $1,084 million and an $800 million bond maturity in September. • As at 30 September 2026, Woodside had liquidity of approximately $7,800 million and net debt (including lease liabilities) of approximately $8,900 million. Capital Markets Day • Woodside’s 2026 Capital Markets Day will be held on Thursday, 5 November 2026, commencing at 10:00 am AEDT/7:00 am AWST/5:00 pm CST (Wednesday, 4 November 2026). • A live webcast of the Australian event will be available on Woodside’s website at https:// meetings.lumiconnect.com/300-191-159-742. • This will be followed by a US Capital Markets Day on 12 November 2026 in New York. Upcoming events 2026-2027 November 5 2026 Capital Markets Day (Australia) 12 2026 Capital Markets Day (United States) January 28 Fourth Quarter Report February 23 2026 Annual Report April 21 First Quarter Report Contacts INVESTORS MEDIA REGISTERED ADDRESS 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 Vanessa Martin Dan Pagoda M: +61 477 397 961 M: +61 482 675 731 E: investor@woodside.com E: dan.pagoda@woodside.com This announcement was approved and authorised for release by Woodside’s Disclosure Committee. 7 | Third quarter report for period ended 30 September 2026
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Production volumes Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 Gas MMscf/d 1,697 1,326 1,827 1,534 1,831 Liquids Mbbl/d 202 214 231 212 228 Ammonia kT/d 0.8 1.8 – 1.3 – Total production volumes Mboe/d 503 454 552 486 549 Production (reserves) Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 AUSTRALIA LNG North West Shelf Mboe 5,646 5,491 5,895 16,815 17,665 Pluto10 Mboe 12,516 7,701 12,118 31,208 33,272 Wheatstone Mboe 1,338 1,454 2,677 5,078 7,523 Total Mboe 19,500 14,646 20,690 53,101 58,460 Pipeline gas Bass Strait Mboe 4,416 3,440 3,929 10,612 10,774 Other10,11 Mboe 2,862 2,510 3,830 7,880 11,450 Total Mboe 7,278 5,950 7,759 18,492 22,224 Crude oil and condensate North West Shelf Mbbl 1,054 949 1,093 2,956 3,111 Pluto10 Mbbl 889 602 980 2,336 2,717 Wheatstone Mbbl 239 271 471 937 1,331 Bass Strait Mbbl 552 477 505 1,371 1,364 Macedon & Pyrenees Mbbl 263 169 347 793 1,274 Ngujima-Yin Mbbl 659 684 960 1,996 2,769 Okha Mbbl 7 - 575 318 1,474 Total Mboe 3,663 3,152 4,931 10,707 14,040 NGL North West Shelf Mbbl 216 191 258 588 695 Pluto10 Mbbl 45 28 58 112 152 Bass Strait Mbbl 772 761 842 2,163 2,263 Total Mboe 1,033 980 1,158 2,863 3,110 Total Australia Mboe 31,474 24,728 34,538 85,163 97,834 Mboe/d 342 272 375 312 358 8 | Third quarter report for period ended 30 September 2026 10 Feed gas volumes purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector are reported under Production (processing). Comparatives have been restated on the same basis. 11 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.
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Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 INTERNATIONAL Pipeline gas USA Mboe 358 405 491 1,209 1,278 Trinidad & Tobago Mboe - - 242 - 4,863 Other12 Mboe - - 6 9 34 Total Mboe 358 405 739 1,218 6,175 Crude oil and condensate Atlantis Mbbl 2,424 2,526 2,783 7,671 7,859 Mad Dog Mbbl 2,710 2,704 2,310 8,172 7,357 Shenzi Mbbl 1,667 1,859 2,088 5,422 6,431 Trinidad & Tobago Mbbl - - 13 - 205 Sangomar Mbbl 6,758 7,854 7,516 21,764 21,922 Other12 Mbbl 35 35 5 124 5 Total Mboe 13,594 14,978 14,715 43,153 43,779 NGL USA Mbbl 276 370 442 1,159 1,238 Other12 Mbbl - - 3 5 18 Total Mboe 276 370 445 1,164 1,256 Total International Mboe 14,228 15,753 15,899 45,535 51,210 Mboe/d 155 173 173 167 188 Total production (reserves) volumes Mboe 45,702 40,481 50,437 130,698 149,044 Mboe/d 497 445 548 479 546 Production (processing) Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 AUSTRALIA Pluto-KGP Interconnector13 LNG Mboe 254 171 210 667 583 Pipeline gas Mboe - - 91 - 253 Crude oil and condensate Mbbl 8 6 9 23 28 NGL Mbbl 5 3 7 12 17 Total Australia Mboe 267 180 317 702 881 Mboe/d 3 2 3 3 3 INTERNATIONAL Beaumont New Ammonia14 Mboe 266 609 - 1,292 - Total International Mboe 266 609 - 1,292 - Mboe/d 3 7 - 5 - Total production (processing) volumes Mboe 533 789 317 1,994 881 Mboe/d 6 9 3 7 3 Total production volumes Mboe 46,235 41,270 50,754 132,692 149,925 Mboe/d 503 454 552 486 549 9 | Third quarter report for period ended 30 September 2026 12 Overriding royalty interests held in the USA for several producing wells. 13 Feed gas volumes purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector, and represents 10% of Pluto-KGP Interconnector volumes. 14 Beaumont New Ammonia production volume is 72.4 kT in Q3 2026 and 351.3 kT in YTD 2026.
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Sales volumes Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 Gas MMscf/d 2,043 1,672 2,122 1,910 2,049 Liquids Mbbl/d 193 227 226 213 226 Ammonia kT/d 1.0 2.1 – 1.3 – Total sales volumes Mboe/d 555 528 599 553 586 Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 AUSTRALIA LNG North West Shelf Mboe 5,630 3,922 4,743 17,016 16,689 Pluto Mboe 13,146 9,011 13,609 34,062 35,254 Wheatstone Mboe 1,967 1,995 1,623 6,578 7,186 Total Mboe 20,743 14,928 19,975 57,656 59,129 Pipeline gas Bass Strait Mboe 4,277 3,736 4,070 10,579 10,989 Other15 Mboe 3,152 2,756 4,028 8,406 11,445 Total Mboe 7,429 6,492 8,098 18,985 22,434 Crude oil and condensate North West Shelf Mbbl 651 1,300 1,194 2,633 3,039 Pluto Mbbl 775 1,011 1,338 2,978 2,693 Wheatstone Mbbl 92 427 417 787 1,402 Bass Strait Mbbl 593 619 531 1,740 1,664 Ngujima-Yin Mbbl 690 963 1,171 2,322 2,985 Okha Mbbl - - - 251 1,256 Macedon & Pyrenees Mbbl - 511 496 512 1,493 Total Mboe 2,801 4,831 5,147 11,223 14,532 NGL North West Shelf Mbbl - 473 430 473 907 Pluto Mbbl - 93 105 93 215 Bass Strait Mbbl 874 437 374 2,177 1,610 Total Mboe 874 1,003 909 2,743 2,732 Total Australia Mboe 31,847 27,254 34,129 90,607 98,827 Mboe/d 346 299 371 332 362 10 | Third quarter report for period ended 30 September 2026 15 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.
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Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 INTERNATIONAL Pipeline gas USA16 Mboe 361 413 438 1,160 1,246 Trinidad & Tobago Mboe - - 243 - 4,750 Other17 Mboe 45 3 4 51 12 Total Mboe 406 416 685 1,211 6,008 Crude oil and condensate Atlantis Mbbl 2,400 2,544 2,801 7,672 7,901 Mad Dog Mbbl 2,605 2,780 2,310 8,118 7,415 Shenzi Mbbl 1,415 1,870 2,094 5,179 6,326 Trinidad & Tobago Mbbl - - 5 - 181 Sangomar Mbbl 6,932 6,865 6,833 20,619 20,859 Other17 Mbbl 130 67 47 286 151 Total Mboe 13,482 14,126 14,090 41,874 42,833 NGL USA Mbbl 254 389 440 1,165 1,196 Other17 Mbbl 29 1 2 32 6 Total Mboe 283 390 442 1,197 1,202 Ammonia Beaumont New Ammonia18 Mboe 346 702 - 1,297 - Total Mboe 346 702 - 1,297 - Total International Mboe 14,517 15,634 15,217 45,579 50,043 Mboe/d 158 172 165 167 183 MARKETING19 LNG Mboe 4,389 4,856 5,492 13,645 10,579 Liquids Mboe 341 298 249 1,023 417 Total Mboe 4,730 5,154 5,741 14,668 10,996 Total Marketing Mboe 4,730 5,154 5,741 14,668 10,996 Total sales volumes Mboe 51,094 48,042 55,087 150,854 159,866 Mboe/d 555 528 599 553 586 11 | Third quarter report for period ended 30 September 2026 16 Restated additional volumes of 0.09 MMboe in Q3 2025 and 0.28 MMboe in YTD 2025 to reflect a revised MMBtu to boe conversion factor. 17 Overriding royalty interests held in the USA for several producing wells. 18 Beaumont New Ammonia sales volumes are 94.2 kT in Q3 2026 and 352.5 kT YTD 2026. 19 Purchased volumes sourced from third parties.
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Operating revenue (US$ million) Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 AUSTRALIA North West Shelf 479 378 323 1,305 1,153 Pluto 1,121 795 1,000 2,682 2,539 Wheatstone 189 167 135 536 589 Bass Strait 380 352 265 964 776 Macedon 56 57 44 169 148 Ngujima-Yin 73 102 88 223 231 Okha - 2 - 27 90 Pyrenees - 45 37 45 120 Revenue from sale of products 2,298 1,898 1,892 5,951 5,646 Intersegment revenue (53) (51) (67) (154) (76) Processing and services revenue 34 35 39 122 148 Total Australia 2,279 1,882 1,864 5,919 5,718 INTERNATIONAL Atlantis 215 258 196 672 568 Mad Dog 227 272 150 689 501 Shenzi 120 192 142 450 447 Trinidad & Tobago20 - - 6 - 150 Sangomar 659 763 477 1,946 1,468 Other21 44 145 2 231 9 Revenue from sale of products 1,265 1,630 973 3,988 3,143 Total International 1,265 1,630 973 3,988 3,143 MARKETING Revenue from sale of products 672 620 452 1,652 996 Intersegment revenue 53 51 67 154 76 Shipping and other revenue 12 2 3 14 16 Total Marketing22 737 673 522 1,820 1,088 Operating revenue23 4,281 4,185 3,359 11,727 9,949 12 | Third quarter report for period ended 30 September 2026 20 Includes the impact of periodic adjustments related to the production sharing contract (PSC). 21 Includes revenue from Beaumont New Ammonia and overriding royalty interests held in the USA for several producing wells. 22 Values include revenue generated from purchased LNG and Liquids volumes, as well as the marketing margin on the sale of Woodside’s produced LNG and Liquids portfolio. Marketing revenue excludes hedging impacts and cargo swaps where a Woodside produced cargo is sold and repurchased from the same counterparty to optimise the portfolio. The margin for these cargo swaps is recognised net in other income. 23 Operating revenue excludes all hedging impacts.
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Realised prices Units Q3 2026 Q2 2026 Q3 2025 Units Q3 2026 Q2 2026 Q3 2025 LNG produced $/MMBtu 13.3 10.5 9.5 $/boe 84 66 60 LNG traded24 $/MMBtu 16.6 15.2 11.2 $/boe 108 99 71 Pipeline gas: Western Australia A$/GJ 6.9 6.9 6.8 East Coast Australia A$/GJ 15.3 15.7 12.9 International25 $/Mcf 2.6 3.0 3.6 Pipeline gas $/boe 49 50 38 Oil and condensate $/bbl 93 107 68 $/boe 93 107 68 NGL $/bbl 52 57 41 $/boe 52 57 41 Liquids traded24 $/bbl 71 110 60 $/boe 71 110 60 Average realised price $/boe 84 85 60 Dated Brent $/bbl 97 105 69 JCC (lagged three months) $/bbl 111 67 75 WTI $/bbl 86 93 65 JKM $/MMBtu 18.9 17.5 12.5 TTF $/MMBtu 18.0 16.4 11.7 13 | Third quarter report for period ended 30 September 2026 24 Excludes any additional benefit attributed to produced volumes through third-party trading activities. 25 Sales volumes have been restated to reflect volumes sold in MMBtu at a revised boe conversion factor impacting realised price by -$0.6/Mcf for International pipeline gas in Q3 2025.
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Capital expenditure (US$ million) Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 Evaluation capitalised26 12 15 8 36 37 Property plant & equipment 1,738 1,557 1,530 4,981 5,902 Cash contributions from participants (1,029) (878) (222) (2,754) (2,092) Other27 1 90 7 96 34 Capital expenditure 722 784 1,323 2,359 3,881 Acquisitions - - - 470 - Total capital expenditure and acquisitions 722 784 1,323 2,829 3,881 Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 Scarborough 186 290 361 751 1,016 Trion 267 275 291 713 698 Louisiana LNG capital expenditure 967 723 498 2,562 3,153 Cash contributions from participants (1,029) (878) (222) (2,754) (2,092) Louisiana LNG other27 7 26 - 38 - Louisiana LNG28 (55) (129) 276 (154) 1,061 Other 324 348 395 1,049 1,106 Capital expenditure 722 784 1,323 2,359 3,881 Other expenditure (US$ million) Exploration and evaluation expenditure Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 Exploration capitalised26,29 3 2 17 45 22 Exploration and evaluation expensed30 63 50 46 163 127 Permit amortisation 2 2 2 6 5 Total 68 54 65 214 154 Trading costs Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 Australia 83 52 71 184 159 International 14 - - 14 - Marketing 407 533 374 1,278 696 Total 504 585 445 1,476 855 Abandonment expenditure Q3 2026 Q2 2026 Q3 2025 YTD 2026 YTD 2025 Total 172 139 141 427 658 14 | Third quarter report for period ended 30 September 2026 26 Project final investment decisions result in amounts of previously capitalised exploration and evaluation expense (from current and prior years) being transferred to property plant & equipment. This table does not reflect the impact of such transfers. 27 Other incorporates Louisiana LNG cash call payments to Williams for Driftwood Pipeline LLC, corporate spend, other investments and other capital expenditure. 28 Louisiana LNG YTD 2026 project spend includes $185 million of prepayments recognised in investing cash flow that are recoverable through partner cash calls but are not yet recognised as capital expenditure. 29 Exploration capitalised represents expenditure on successful and pending wells, plus permit acquisition costs during the period and is net of well costs reclassified to expense on finalisation of well results. 30 Includes seismic and general permit activities and other exploration costs.
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Exploration or appraisal wells drilled Region Permit area Well Target Interest (%) Spud date Water depth (m) Actual well depth (m)31 Remarks Egypt Tiba Nasim-1X Gas 40% Non- operator 25 August 2026 -1 2,650 Drilling, onshore Permits and licences Key changes to permit and licence holdings during the quarter ended 30 September 2026 are noted below. Region Permits or licence areas Change in interest (%) Current interest (%) Remarks United States AC 125, AC 126 (45%) —% Assigned GB 721, GC 598, AC 36, AC 80, AC 81 (100%) —% Relinquished EB 682 100% 100% Awarded 15 | Third quarter report for period ended 30 September 2026 31 Well depths are referenced to the rig rotary table.
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Production rates Average daily production rates (100% project) for the quarter ended 30 September 2026: Woodside share32 Production rate (100% project, Mboe/d) Remarks Q3 2026 Q2 2026 AUSTRALIA NWS Project LNG 29.17% 210 203 Increased production driven by reliability and wells returned to service.Crude oil and condensate 29.26% 39 35 NGL 29.36% 8 7 Pluto LNG LNG 90.00% 124 75 Production higher following planned maintenance turnaround in Q2.Crude oil and condensate 90.00% 10 7 Pluto-KGP Interconnector LNG 100.00% 28 19 Production higher due to major turnaround in Q2 which impacted feed gas.Crude oil and condensate 100.00% 1 1 NGL 100.00% 1 – Wheatstone33 LNG 6.00% 243 204 Julimar Brunello production lower due to impact of offshore project activities.Crude oil and condensate 8.12% 32 28 Bass Strait Pipeline gas 48.95% 98 83 Production higher due to seasonal increases in demand.Crude oil and condensate 43.61% 14 12 NGL 44.96% 19 18 Australia Oil Ngujima-Yin 60.00% 12 13 Okha reconnected late in Q3.Okha 50.00% – – Pyrenees 71.43% 4 3 Other Pipeline gas34 31 28 16 | Third quarter report for period ended 30 September 2026 32 Woodside share reflects the net realised interest for the period. 33 The Wheatstone asset processes gas from several offshore gas fields, including the Julimar and Brunello fields, for which Woodside has a 65% participating interest and is the operator. 34 Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.
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Woodside share35 Production rate (100% project, Mboe/d) Remarks Q3 2026 Q2 2026 INTERNATIONAL Atlantis Crude oil and condensate 38.50% 68 72 Production lower due to higher planned and unplanned events.NGL 38.50% 3 5 Pipeline gas 38.50% 7 8 Mad Dog Crude oil and condensate 20.86% 141 142 NGL 20.86% 5 5 Pipeline gas 20.86% 4 3 Shenzi Crude oil and condensate 64.55% 28 32 Production lower because of planned shutdown and well interventions.NGL 64.65% 1 2 Pipeline gas 64.64% 1 1 Sangomar Crude oil 78.01%36 94 99 Production lower due to natural field decline. Beaumont New Ammonia Ammonia37 100.00% 3 7 Production lower due to unplanned event. 17 | Third quarter report for period ended 30 September 2026 35 Woodside share reflects the net realised interest for the period. 36 Operations governed by production sharing contracts. 37 Beaumont New Ammonia production rate was 0.8 kT/d in Q3 2026.
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Disclaimer and important notice Forward looking statements This report 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 but not limited to, statements regarding the timing, completion and outcomes of transactions, construction costs and capital expenditures, supply and demand for Woodside’s products, development, completion and execution of Woodside’s projects, the expected benefits, cash flows and rates of return or other future results of investments, strategies and transactions, the payment of future dividends and the amount thereof, future results of projects, operating activities and new energy products, expectations and plans for renewables production capacity and investments in, and development of, renewables projects, expectations and guidance with respect to production, production costs and other costs, capital expenditure, abandonment expenditure, exploration expenditure and gas hub exposure, trends in commodity prices and currency exchange rates, adoption and implementation of new technologies and expectations regarding the achievement of Woodside’s Scope 1 and 2 greenhouse gas emissions target (in each case on a net equity or gross equity basis as specified) and other climate 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”, “enable”, “estimate”, “expect”, “forecast”, “foresee”, “guidance”, “intend”, “likely”, “may”, “objective”, “outlook”, “pathway”, “plan”, “position”, “potential”, “project”, “schedule”, “seek”, “should”, “strategy”, “strive”, “target”, “will” and other similar words or expressions. Forward-looking statements in this report are not guarantees of future events or performance, but are in the nature of future expectations that are based on management’s current expectations and assumptions. 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, contingencies 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 the assumptions on which they are based include, but are not limited to, fluctuations in commodity prices, actual demand for Woodside 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, pace of technology developments, sustainability and environmental risks, climate related transition and physical risks, safety and personnel risks, changes in accounting standards, economic and financial markets conditions in various countries and regions, the actions of third parties, project delay or advancement, regulatory approvals, political risks and 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 those related to the imposition of tariffs and other trade restrictions, and 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 conditions, inflationary conditions, prevailing exchange rates and interest rates and conditions in financial markets and risks associated with acquisitions, mergers, divestitures, 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 more detailed summary of the key risks relating to Woodside and its business can be found in the “Risk factors” 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 report. 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 report. Investors are strongly cautioned that forward-looking statements are subject to significant uncertainties and may not prove to be correct. Actual results or performance may vary materially from those expressed in, or implied by, any forward-looking statements. None of Woodside nor any of its related bodies corporate, nor any of their respective officers, directors, employees, advisers or representatives, nor any person named in this report or involved in the preparation of the information in this report, makes any representation, assurance, guarantee or warranty (either express or implied) as to the accuracy or likelihood of fulfilment of any forward-looking statement, or any outcomes, events or results expressed or implied in any forward-looking statement in this report. All forward-looking statements contained in this report reflect Woodside’s views held as at the date of this report and, except as required by applicable law, neither Woodside, its related bodies corporate, nor any of their respective officers, directors, employees, advisers or representatives nor any person named in this report or involved in the preparation of the information in this report intends to, undertakes to, or assumes any obligation to, provide any additional information or update or revise any of 18 | Third quarter report for period ended 30 September 2026
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these statements after the date of this report, either to make them conform to actual results or as a result of new information, future events or results, changes in Woodside’s expectations or otherwise. Past performance (including historical financial and operational information) is given for illustrative purposes only. It is not necessarily a reliable indicator of future performance, including future security prices. Other important information Unless otherwise stated, all: • figures are Woodside share for the quarter ending 30 September 2026; • references to dollars, cents or $ in this report are to US currency; and • references to ‘Woodside’, ‘the company’, ‘the Group’, ‘we’, ‘us’ and ‘our’ refer to Woodside Energy Group Ltd and its controlled entities as a whole. Glossary, units of measure and conversion factors Refer to the Glossary in the Half-Year Report 2026 for definitions, including carbon related definitions. Product Unit Conversion factor Natural gas 5,700 scf 1 boe Condensate 1 bbl 1 boe Oil 1 bbl 1 boe Natural gas liquids 1 bbl 1 boe Ammonia 1 metric tonne 3.68 boe Facility Unit LNG Conversion factor Karratha Gas Plant 1 tonne 8.08 boe Pluto LNG Gas Plant 1 tonne 8.34 boe Wheatstone 1 tonne 8.27 boe The LNG conversion factor from tonne to boe is specific to volumes produced at each facility and is based on gas composition which may change over time. 19 | Third quarter report for period ended 30 September 2026
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Term Definition bbl barrel bcf billion cubic feet of gas boe barrel of oil equivalent GJ gigajoule kT thousand metric tonnes kT/d thousand metric tonnes per day NGL natural gas liquid Mbbl thousand barrels Mbbl/d thousand barrels per day Mboe thousand barrels of oil equivalent Mboe/d thousand barrels of oil equivalent per day Mcf thousand cubic feet of gas MMboe million barrels of oil equivalent MMBtu million British thermal units MMscf/d million standard cubic feet of gas per day Mtpa million tonnes per annum PJ petajoule scf standard cubic feet of gas TJ terajoule 20 | Third quarter report for period ended 30 September 2026