WDS 6-K
Woodside Energy Group Ltd (WDS)
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 6-K
REPORT OF FOREIGN PRIVATE ISSUER
PURSUANT TO RULE 13a-16 OR 15d-16
UNDER THE SECURITIES EXCHANGE ACT OF 1934
For the month of October 2025
Commission File Number: 001-41404
Woodside Energy Group Ltd
(ABN 55 004 898 962)
(Registrant’s name)
Woodside Energy Group Ltd
Mia Yellagonga, 11 Mount Street
Perth, Western Australia 6000
Australia
(Address ofprincipal executive offices)
Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.
Form 20-F ☑ Form 40-F ☐
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1): ☐
Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7): ☐
EXHIBIT INDEX
| Exhibit No. | Description |
|---|---|
| 99.1 | A copy of the registrant’s ASX Announcement, dated October 22, 2025, entitled “Third Quarter 2025 Report”. |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
Dated: October 22, 2025
| WOODSIDE ENERGY GROUP LTD | |
|---|---|
| By: | /s/ Damien Gare |
| Damien Gare<br> <br>Corporate Secretary |
EX-99.1
Exhibit 99.1
THIRD QUARTER REPORT FOR PERIOD ENDED 30 SEPTEMBER 2025
ASX: WDS | NYSE: WDS
Wednesday, 22 October 2025
Sangomar extends its run
Quarterly performance highlights
| • | Quarterly production of 50.8 MMboe (552 Mboe/d), up 1% from Q2 2025. Full-year 2025 production guidance has been revised to 192 – 197 MMboe. |
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| • | Continued exceptional performance from Sangomar, with 99 Mbbl/d produced (100% basis, 82 Mbbl/d Woodside share), generating $477 million revenue for the quarter. |
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| • | Achieved outstanding Pluto LNG reliability of 100% for the quarter. |
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| • | Achieved an average realised quarterly price of $60/boe, benefiting from diversified pricing and optimisation. |
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Project highlights
| • | The Scarborough Energy Project was 91% complete, and is on track for first LNG in the second half of 2026. |
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| • | The Beaumont New Ammonia Project was 97% complete, with Phase 1 targeting first ammonia production from late 2025. |
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| • | The Trion Project was 43% complete, and is targeting first oil in 2028. |
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| • | The Louisiana LNG Project, comprising three trains, was 19% complete. Train 1 was 25% complete and is targeting first LNG in 2029. |
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Business and portfolio highlights
| • | Received the final environmental approval from the Australian Government on the North West Shelf Project Extension. The approval enables continued operations beyond 2030, allowing increased resource recovery and other<br>resource owners gas processing subject to rigorous conditions. | |||
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| • | Agreed to assume operatorship of the Bass Strait assets, unlocking potential development of additional gas resources, with completion targeted in 2026. | |||
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| • | Completed the divestment of the Greater Angostura assets, receiving cash of $259 million.^1^ | |||
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| • | Entered into a sale and purchase agreement with PETRONAS and a heads of agreement with BOTAŞ for the long-term supply of LNG.^2^ | |||
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| 2025 full-year guidance | Prior | Current | Comments | |
| --- | --- | --- | --- | --- |
| Production | MMboe | 188 - 195 | 192 - 197 | Continued strong performance across assets |
| Unit production cost | $/boe | 8.0 - 8.5 | 7.6 - 8.1 | Continued strong performance from Sangomar and US assets |
| Property, plant and equipment depreciation and amortisation | $ million | 4,700 - 5,000 | 4,800 - 5,100 | |
| Exploration expenditure | $ million | 200 | No change | |
| Payments for restoration | $ million | 700 - 1,000 | No change | |
| Gas hub exposure^3^ | % of produced LNG | 28 - 35 | 27 - 31 | |
| Capital expenditure (excluding Louisiana LNG)^4^^,^^5^ | $ million | 4,000 - 4,500 | 3,700 - 4,000 | Timing of sustaining capital expenditure and Scarborough; no impact to total cost or start-up schedule. |
| Louisiana LNG expenditure^5,^^6^ | $ million | 1,000 - 1,200 | No change | |
| ^1^ | Includes a base purchase price of $206 million plus working capital completion adjustments, based on an<br>effective date of 1 January 2025. | |||
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| ^2^ | The BOTAŞ supply arrangement is subject to the parties entering a binding sales and purchase agreement.<br> | |||
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| ^3^ | Gas hub indices include Japan Korea Marker (JKM), TTF and National Balancing Point (NBP). It excludes Henry<br>Hub. | |||
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| ^4^ | Capital expenditure includes the following participating interests; Scarborough (74.9%), Pluto Train 2 (51%)<br>and Trion (60%). It excludes the remaining Beaumont New Ammonia acquisition expenditure and Louisiana LNG expenditure. | |||
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| ^5^ | The guidance assumes no change to participating interests in 2025. | |||
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| ^6^ | Lousiana LNG (100% Louisiana LNG LLC and 60% Louisiana LNG Infrastructure LLC) capital expenditure adjusted for<br>the cash contributions from Stonepeak. | |||
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| 1 | Third quarter report for period ended 30 September 2025 | |||
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Woodside CEO Meg O’Neill said the company maintained excellent operational performance over the quarter, while efficiently executing a global portfolio of growth projects to drive long-term shareholder value.
“Woodside delivered increased quarterly production of 51 million barrels of oil equivalent. Sangomar maintained its exceptional performance, producing 99 thousand barrels of oil per day at 98.2% reliability. Our Australian assets also demonstrated outstanding reliability of 100% at Pluto LNG and 99.9% at the North West Shelf Project.
“We received final Australian Government approval during the quarter for the North West Shelf Project Extension, providing certainty for ongoing operations and reliable energy supply from this high-quality asset.
“Our agreement to assume operatorship of the Bass Strait assets further strengthens Woodside’s Australian operations portfolio and unlocks potential development of additional gas resources.
“We continued safe delivery of Woodside’s major growth projects to schedule and budget.
“Strong momentum on delivery of the Scarborough Energy Project continues, which is now 91% complete and on track for first LNG in the second half of 2026. During the quarter, three more development wells were drilled with reservoir quality and well deliverability expectations in line with pre-drill estimates, and pre-commissioning of the subsea infrastructure was completed.
“Our Beaumont New Ammonia Project is 97% complete, with key systems now operational and commissioning activities underway. We continue to target first ammonia production in late 2025.
“Our Louisiana LNG Project, comprising three trains, has ramped up with more than 1,000 personnel now on site and construction is 19% complete. Strong support for the project from state and federal governments and the Louisiana community was in evidence at our groundbreaking ceremony in September.
“Customer demand for Woodside’s LNG remains robust. Our fully termed sales and purchase agreement with PETRONAS will see Woodside supply one million tonnes per annum of LNG to Malaysia from 2028 for a 15-year period. Under our heads of agreement with BOTAŞ, Woodside will supply the Turkish company with approximately 0.5 million tonnes per annum of LNG over nine years from 2030, subject to entering a binding sales and purchase agreement.
“Woodside continues to support our customers’ decarbonisation efforts. During the quarter, we signed a memorandum of understanding with Japan Suiso Energy and The Kansai Electric Power Co. to collaborate on the proposed development of a liquid hydrogen supply chain between Western Australia and Japan, centred on our proposed H2Perth Project. The Premier of Western Australia attended the signing event, highlighting the significance of this opportunity.”
| 2 | Third quarter report for period ended 30 September 2025 |
|---|
Comparative performance at a glance
| Q3<br><br><br>2025 | Q2 2025 | Change<br><br><br>% | Q3 2024 | Change<br><br><br>% | YTD<br><br><br>2025 | YTD<br><br><br>2024 | Change<br><br><br>% | ||
|---|---|---|---|---|---|---|---|---|---|
| Revenue^7^ | $ million | 3,359 | 3,275 | 3% | 3,707 | (9%) | 9,949 | 9,695 | 3% |
| Production^8^ | MMboe | 50.8 | 50.1 | 1% | 53.1 | (4%) | 149.9 | 142.4 | 5% |
| Gas | MMscf/d | 1,827 | 1,825 | — | 2,001 | (9%) | 1,831 | 1,939 | (6%) |
| Liquids | Mbbl/d | 231 | 230 | — | 226 | 2% | 228 | 180 | 27% |
| Total | Mboe/d | 552 | 550 | —% | 577 | (4%) | 549 | 520 | 6% |
| Sales^9^ | MMboe | 55.0 | 54.4 | 1% | 56.1 | (2%) | 159.6 | 149.9 | 6% |
| Gas | MMscf/d | 2,116 | 2,050 | 3% | 2,172 | (3%) | 2,043 | 2,079 | (2%) |
| Liquids | Mbbl/d | 226 | 238 | (5%) | 228 | (1%) | 226 | 182 | 24% |
| Total | Mboe/d | 598 | 598 | —% | 609 | (2%) | 585 | 547 | 7% |
| Average realisedprice | $/boe | 60 | 59 | 2% | 65 | (8%) | 61 | 63 | (3%) |
| Capital expenditure | $ million | 1,323 | 752 | 76% | 3,033 | (56%) | 3,881 | 5,423 | (28%) |
| Capex excluding LouisianaLNG^10^ | $ million | 1,047 | 868 | 21% | 1,133 | (8%) | 2,820 | 3,523 | (20%) |
| Louisiana LNG^11^ | $ million | 276 | (116) | 338% | — | — | 1,061 | — | — |
| Acquisitions | $ million | — | — | — | 1,900 | (100%) | — | 1,900 | (100%) |
Operations
Pluto LNG
| • | Achieved quarterly LNG reliability of 100%. |
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| • | The XNA-03 infill well is progressing toward RFSU, targeted in H1 2026.<br> |
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North West Shelf (NWS) Project
| • | Achieved strong quarterly LNG reliability of 99.9%. |
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| • | Completed planned maintenance offshore at North Rankin and onshore at Karratha Gas Plant (KGP), with production<br>recommencing as planned. |
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| • | Successfully started the Lambert West development well, tied back to the Angel platform.<br> |
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| • | Received the final environmental approval from the Australian Government on the NWS Project Extension, enabling<br>processing of remaining infill and near-field opportunities from existing NWS reserves beyond 2030 and gas from other resource owners. Woodside has assessed the work required to meet the federal conditions; there is no material increase expected to<br>forecast capital expenditure to maintain ongoing North West Shelf production. The federal conditions provide clarity on the modifications required at KGP that will support processing of other resource owners’ gas. |
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| • | Subsequent to the quarter, two separate legal proceedings were commenced in the Federal Court of Australia<br>challenging the Australian Government’s decision to approve the NWS Project Extension. |
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Wheatstone and Julimar-Brunello
| • | Progressed the Julimar Phase 3 Project, a four-well tieback to the existing Julimar field production<br>system. Drilling activities commenced in the quarter, with project startup targeted in 2026. |
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| • | Completion of the asset swap with Chevron remains targeted for<br>2026.^12^ |
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| ^7^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of<br>$28 million in Q3 2024 and $14 million in YTD 2024. These amounts will be included within other income/(expenses) in the Financial Statements. Restatement allows for revenue presented in this quarterly report to reconcile to operating<br>revenue, the IFRS measure presented in Woodside Financial Statements. |
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| ^8^ | Q3 2025 includes 0.32 MMboe primarily from feed gas purchased from Pluto<br>non-operating participants processed through the Pluto-KGP Interconnector. Percent change in total production may differ from percent change in daily production due to<br>the number of days in each quarter. |
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| ^9^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.29<br>MMboe in Q3 2024 and 0.20 MMboe in YTD 2024. Restatement allows for revenue presented in this quarterly report to reconcile to operating revenue, the IFRS measure presented in Woodside Financial Statements. |
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| ^10^ | Includes capital additions on property plant and equipment, evaluation capitalised and other corporate spend.<br>Exploration capitalised has been reclassified from capital expenditure to other expenditure. |
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| ^11^ | Capital expenditure for Louisiana LNG is presented as a net figure inclusive of cash contributions received<br>from Stonepeak representing its share of the project’s capital expenditure to date. Q3 2025 includes a $222 million cash contribution. |
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| ^12^ | Completion of the transaction is subject to conditions precedent. |
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| 3 | Third quarter report for period ended 30 September 2025 |
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Bass Strait
| • | Agreed to assume operatorship of the Bass Strait assets from ExxonMobil Australia, with completion targeted for<br>2026.^13^ Four potential development wells have been identified that could deliver up to 200 PJ of sales gas to the market, subject to further technical maturation and a final investment decision.<br>This potential production has been identified from within the existing contingent resource opportunity set.^14^ |
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| • | Delivered reliability of 90.5% during the peak winter period, the first winter post completion of the<br>Gippsland Asset Streamlining Project. |
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| • | Progressed the Kipper 1B Project with drilling activities completed subsequent to the end of the period.<br> |
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Sangomar
| • | Achieved average daily production rate of 99 Mbbl/d (100% basis, 82 Mbbl/d Woodside share) at 98.2%<br>reliability. |
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| • | Strong field performance in the S500 reservoirs resulted in an additional 18.4 million barrels of<br>proved (1P) reserves being added in July.^15^ |
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| • | Production from the Sangomar field remained on plateau through the quarter, with the field expected to<br>come off plateau during Q4 2025. |
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| • | Recognised as International Local Content Champion of the Year by African Energy Week 2025 for commitment<br>to building local capacity and fostering skills transfer. |
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United States of America
| • | Achieved strong quarterly production at Shenzi, supported by reliability of 97.1%. |
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| • | Commenced drilling activities on the Atlantis Drill Center 1 Expansion Project. |
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| • | Achieved first production from the Argos Southwest Extension Project in August, 25 months after finishing<br>the appraisal well. |
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Greater Angostura
| • | On 11 July 2025, completed the divestment of the Greater Angostura assets to Perenco which includes<br>Woodside’s interest in the shallow water Angostura and Ruby offshore oil and gas fields, associated production facilities, and onshore terminal, receiving cash of $259 million.^16^<br> |
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Marketing
| • | Signed a fully termed sales and purchase agreement with PETRONAS LNG Ltd, a subsidiary of Petroliam Nasional<br>Berhad (PETRONAS), for the supply of 1 Mtpa of LNG to Malaysia from 2028 for a period of 15 years. |
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| • | Signed a heads of agreement with Boru Hatlarıile Petrol Taşıma A.Ş. (BOTAŞ), for the<br>supply of approximately 0.5 Mtpa of LNG from 2030, for a period of up to nine years. Supply will primarily be from the Louisiana LNG Project. The supply arrangement is subject to the parties entering a binding sales and purchase agreement.<br> |
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| • | Woodside held a naming ceremony for two new LNG charter vessels, the Woodside Jirrubakura and the Woodside<br>Barrumbara. The Woodside Jirrubakura was delivered during the quarter and will support the start-up of the Scarborough Energy Project. |
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| • | Executed incremental pipeline gas sales of: |
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| • | 4.9 PJ in Western Australia for delivery in 2025. Woodside continues to engage with the Western Australian<br>domestic market on additional spot supply and requirements for 2026 and 2027. |
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| • | 29.2 PJ in Eastern Australia for delivery in 2026 and 2027. |
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| • | Supplied 29.8% of produced LNG at prices linked to gas hub indices in the quarter, realising a $2.4/MMBtu<br>premium compared to oil-linked pricing. This represents 10.9% of Woodside’s total equity production.<br> |
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| ^13^ | The transaction is subject to customary conditions precedent (including obtaining regulatory approvals).<br> |
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| ^14^ | Refer to Woodside’s Reserves and Resources Statement dated 17 February 2025 for further information<br>on the Bass Strait reserves and resources. |
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| ^15^ | Refer to page 8 of Woodside’s Half-Year Report 2025 dated 19 August 2025 and to Notes to petroleum<br>reserves and resources on page 20 for details of disclaimers. |
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| ^16^ | Includes a base purchase price of $206 million plus working capital completion adjustments, based on an<br>effective date of 1 January 2025. |
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| 4 | Third quarter report for period ended 30 September 2025 |
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Business Development
| • | Signed a non-binding memorandum of understanding with Hyundai Engineering<br>and Hyundai Glovis, establishing a strategic framework to collaborate on LNG project development, engineering services and shipping logistics. |
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Projects
Scarborough Energy Project
| • | The Scarborough and Pluto Train 2 Projects were 91% complete at the end of the quarter (excluding Pluto<br>Train 1 modifications). |
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| • | Continued integration and commissioning activities for the floating production unit ahead of China<br>departure in November. |
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| • | Continued drilling of the development wells with the fourth, fifth and sixth wells drilled and completed.<br>Subsequent to the period, the seventh development well was drilled. Reservoir quality and well deliverability expectations continue to be in line with pre-drill estimates. |
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| • | Completed the installation, testing and pre-commissioning of the<br>subsea infrastructure. |
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| • | Pluto Train 2 workforce numbers remain at peak levels. Key activities include piping and electrical<br>installation, system testing and commissioning. |
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| • | Completed installation of structural decks on the Pluto Train 1 modifications modules. Key activities<br>include piping, electrical and equipment installation. |
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| • | The Federal Court of Australia confirmed the validity of the National Offshore Petroleum and Safety and<br>Environmental Management Authority’s acceptance of the Scarborough Offshore Facility and Trunkline (Operations) Environment Plan. |
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| • | First LNG cargo is on track for the second half of 2026. |
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Beaumont New Ammonia
| • | The Beaumont New Ammonia Project was 97% complete at the end of the quarter. |
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| • | Pre-commissioning and commissioning activities for Train 1 remain<br>underway. Key systems are now operational. |
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| • | Catalyst loading in the ammonia converter has begun and commissioning of critical equipment is scheduled<br>to begin in October. |
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| • | First ammonia production is targeted for late 2025, subject to satisfying the commissioning and startup<br>requirements for the facility. |
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| • | Project completion and associated payment of the remaining 20% of the acquisition consideration is<br>expected in 2026. |
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Trion
| • | The Trion Project was 43% complete at the end of the quarter. |
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| • | Progressed fabrication of the floating production unit hull and topside. |
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| • | Commenced fabrication and progressed detailed engineering of the floating storage and offloading unit.<br> |
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| • | Progressed manufacturing of subsea equipment, with the first manifold completed. |
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| • | Received regulatory approval for the Environmental Impact Assessment. |
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| • | First oil is targeted for 2028. |
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Louisiana LNG
| • | The Louisiana LNG Project, comprising three trains, was 19% complete and first LNG is targeted for 2029.<br> |
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| • | Train 1 was 25% complete at the end of the quarter. First deliveries of structural steel and process piping were<br>received for Train 1 construction. |
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| • | Train 2 and 3 were 14% and 12% complete respectively at the end of the quarter. Foundation work for both are<br>underway. |
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| • | Commenced LNG tank vertical construction. |
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| • | Continued focus on progressing the marine offloading facility, marine dry excavation, and civil works.<br> |
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| • | Progressed securing rights of way for new build pipeline (Line 200) to terminal, currently secured 55% by length.<br> |
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| 5 | Third quarter report for period ended 30 September 2025 |
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| • | Received approval of the Quality Jobs incentive application from the Louisiana Board of Commerce and<br>Industry. The incentive is estimated to provide $132 million in rebates for the Project. |
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Hydrogen Refueller @H2Perth
| • | The Hydrogen Refueller @H2Perth is a self-contained hydrogen production, storage and refuelling station<br>located in Perth, Western Australia. |
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| • | Commissioning activities have commenced on site in preparation, ready for startup in Q4 2025.<br> |
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| • | First hydrogen production is targeting the first half of 2026.^17^ |
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Decommissioning
| • | Recommenced offshore decommissioning execution activities on Stybarrow and Griffin in accordance with<br>revised General Direction requirements. |
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| • | Completed removal of xmas trees from the ten Stybarrow wells and commenced removal of associated wellheads<br>with four wellheads removed in Q3. |
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| • | Completed removal of Griffin mid-depth buoy chains.<br> |
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| • | Commenced preparations for planned removal of the Echo Yodel umbilical in Q4 2025. |
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| • | In Bass Strait, 11 wells were plugged in the quarter. Received funding approval for the offshore platform removal<br>campaign 1 project and progressed environmental approvals. |
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Exploration and development
Browse
| • | In August, the Western Australian Environmental Protection Authority accepted an amendment to the Browse to North<br>West Shelf Project proposal, which reflects changes to the development footprint and new environmental measures. |
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| • | In September, the Department of Climate Change, Energy, the Environment and Water (DCCEEW) accepted the<br>corresponding amendment to the Commonwealth Browse to North West Shelf Project proposal. |
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| • | Following the referral of the Browse CCS Project in October 2024, awaiting a decision by DCCEEW on the assessment<br>approach and corresponding level of assessment for the Browse CCS Project environmental proposal under the Environment Protection and Biodiversity Conservation Act. |
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| • | Engaged contractors to progress pre-FEED engineering scopes for floating<br>production, storage and offtake facilities. |
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Sunrise
| • | Woodside remains engaged with both the Timor-Leste and Australian Governments, as well as the Sunrise<br>Joint Venture participants, to evaluate and address technical and commercial factors that support the intended development of the fields. |
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| • | Following Woodside’s visit to Timor-Leste’s south coast as a potential location for processing<br>Sunrise gas, a reciprocal visit was hosted in Karratha and Perth for the Timor-Leste Minister of Petroleum and Mineral Resources and a senior Timorese delegation to demonstrate Woodside’s LNG project execution skills and capabilities.<br> |
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Calypso
| • | The Calypso Joint Venture continues to review development options. Concept select engineering studies to mature<br>the technical and commercial definition were completed in Q3. |
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Exploration
| • | Acquired 17.5% working interest across five blocks in the Green Canyon (United States) offshore area.<br> |
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| • | The Bandit-1 well<br>(non-operated) was spud in September 2025 in permit area GC 680. |
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| ^17^ | The project has received funding from the Hydrogen Fuelled Transport Project Funding Process as part of the<br>Western Australian Government’s Renewable Hydrogen Strategy. |
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| 6 | Third quarter report for period ended 30 September 2025 |
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New energy and carbon solutions
H2 Perth
| • | Woodside Energy, Japan Suiso Energy, Ltd. and The Kansai Electric Power Co., Inc. have signed a memorandum<br>of understanding to collaborate on the development of a liquid hydrogen supply chain between Australia and Japan, centered on Woodside’s proposed H2Perth Project. |
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Carbon capture and storage (CCS) opportunities
| • | The Bonaparte CCS Assessment Joint Venture continued with<br>pre-front end engineering design. |
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| • | Woodside continues to assess the South East Australia CCS opportunity. |
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Corporate activities
Climate and sustainability
| • | On track to meet Woodside’s target of reducing net equity Scope 1 and 2 greenhouse gas emissions by<br>15% by 2025.^18^^,^^19^ |
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| • | Released Woodside’s 2024 Reconciliation Action Plan Report. The report outlines progress against<br>four pillars: Respect for Culture and Heritage, Capability and Capacity, Economic Participation and Stronger Communities. |
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Hedging
| • | As at 30 September 2025, delivered approximately 83% of the 30 MMboe of 2025 oil production that was<br>previously hedged at an average price of $78.7 per barrel. |
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| • | The realised value of all hedged positions for the period ended 30 September 2025 is an estimated pre-tax profit of $139 million, with a $135 million profit related to oil price hedges offset by a $16 million loss related to Corpus Christi hedges, and a $20 million profit related to other<br>hedge positions. Hedging profits will be included in ‘other income’ except hedging profits related to interest rate swaps which will be included in ‘finance income’ in the financial statements. |
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Funding and liquidity
| • | As at 30 September 2025, Woodside had liquidity of approximately<br>$8,300 million. |
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Embedded commodity derivative
| • | In 2023, Woodside entered into a revised long-term gas sale and purchase contract with Perdaman. A<br>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. |
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| • | As there is no long-term urea forward curve, Title Transfer Facilities (TTF) continues to be used as a<br>proxy to simulate the value of the derivative over the life of the contract. |
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| • | For the quarter ended 30 September 2025, an unrealised loss of approximately $15 million is<br>expected to be recognised through other income. |
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Capital Markets Day
| • | Woodside’s Capital Markets Day 2025 will be held on Wednesday, 5 November 2025, commencing at 9:30<br>AEDT / 6:30 AWST / 16:30 CST (Tuesday, 4 November 2025). |
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| • | A live webcast of the event will be available at<br>https://meetings.lumiconnect.com/300-031-281-118. |
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Upcoming events 2025-2026
| November | 5 | Capital Markets Day |
|---|---|---|
| January | 28 | Fourth quarter 2025 report |
| February | 24 | 2025 Annual Report |
| ^18^ | Targets are for net equity Scope 1 and 2 greenhouse gas emissions relative to a starting base of 6.32 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<br>or sanctioned assets with a final investment decision prior to 2021. Net equity emissions include the utilisation of carbon credits as offsets. | |
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| ^19^ | This means net equity Scope 1 and 2 greenhouse gas emissions for the<br>12-month period ending 31 December 2025 are targeted to be 15% lower than the starting base. | |
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| 7 | Third quarter report for period ended 30 September 2025 | |
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| Contacts: | ||
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| INVESTORS | MEDIA | REGISTERED ADDRESS |
| Woodside Energy Group Ltd | ||
| ACN 004 898 962 | ||
| Vanessa Martin | Christine Abbott | Mia Yellagonga |
| M: +61 477 397 961 | M: +61 484 112 469 | 11 Mount Street |
| E: [email protected] | E: [email protected] | Perth WA 6000 |
| Australia | ||
| T: +61 8 9348 4000 | ||
| www.woodside.com |
This announcement was approved and authorised for release by Woodside’s Disclosure Committee.
| 8 | Third quarter report for period ended 30 September 2025 |
|---|
Production summary
| Q3 2025 | Q2 2025 | Q3 2024 | YTD 2025 | YTD 2024 | |||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Gas | MMscf/d | 1,827 | 1,825 | 2,001 | 1,831 | 1,939 | |||||
| Liquids | Mbbl/d | 231 | 230 | 226 | 228 | 180 | |||||
| Total | Mboe/d | **** | 552 | **** | 550 | **** | 577 | **** | 549 | **** | 520 |
| Q3<br><br><br>2025 | Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
| AUSTRALIA | |||||||||||
| LNG | |||||||||||
| North West Shelf | Mboe | 5,895 | 5,375 | 7,029 | 17,665 | 22,309 | |||||
| Pluto^20^ | Mboe | 12,328 | 11,097 | 12,007 | 33,855 | 35,487 | |||||
| Wheatstone | Mboe | 2,677 | 2,424 | 2,565 | 7,523 | 6,881 | |||||
| Total | Mboe | 20,900 | 18,896 | 21,601 | 59,043 | 64,677 | |||||
| Pipeline gas | |||||||||||
| Bass Strait | Mboe | 3,929 | 3,653 | 4,069 | 10,774 | 9,838 | |||||
| Other^21^ | Mboe | 3,921 | 3,975 | 4,016 | 11,703 | 11,142 | |||||
| Total | Mboe | 7,850 | 7,628 | 8,085 | 22,477 | 20,980 | |||||
| Crude oil and condensate | |||||||||||
| North West Shelf | Mbbl | 1,093 | 912 | 1,265 | 3,111 | 3,937 | |||||
| Pluto^20^ | Mbbl | 989 | 899 | 966 | 2,745 | 2,830 | |||||
| Wheatstone | Mbbl | 471 | 419 | 474 | 1,331 | 1,316 | |||||
| Bass Strait | Mbbl | 505 | 457 | 701 | 1,364 | 1,696 | |||||
| Macedon & Pyrenees | Mbbl | 347 | 558 | 633 | 1,274 | 849 | |||||
| Ngujima-Yin | Mbbl | 960 | 1,084 | 1,231 | 2,769 | 3,091 | |||||
| Okha | Mbbl | 575 | 587 | 615 | 1,474 | 1,572 | |||||
| Total | Mboe | 4,940 | 4,916 | 5,885 | 14,068 | 15,291 | |||||
| NGL | |||||||||||
| North West Shelf | Mbbl | 258 | 207 | 288 | 695 | 857 | |||||
| Pluto^20^ | Mbbl | 65 | 52 | 55 | 169 | 168 | |||||
| Bass Strait | Mbbl | 842 | 753 | 1,152 | 2,263 | 2,925 | |||||
| Total | Mboe | 1,165 | 1,012 | 1,495 | 3,127 | 3,950 | |||||
| TotalAustralia^22^ | Mboe | **** | 34,855 | **** | 32,452 | **** | 37,066 | **** | 98,715 | **** | 104,898 |
| Mboe/d | **** | 379 | **** | 357 | **** | 403 | **** | 362 | **** | 383 | |
| ^20^ | Q3 2025 includes 2.10 MMboe of LNG, 0.09 MMboe of condensate and 0.07 MMboe of NGL processed at the Karratha<br>Gas Plant (KGP) through the Pluto-KGP Interconnector. | ||||||||||
| --- | --- | ||||||||||
| ^21^ | Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.<br> | ||||||||||
| --- | --- | ||||||||||
| ^22^ | Q3 2025 includes 0.32 MMboe primarily from feed gas purchased from Pluto<br>non-operating participants processed through the Pluto-KGP Interconnector. | ||||||||||
| --- | --- | ||||||||||
| 9 | Third quarter report for period ended 30 September 2025 | ||||||||||
| --- | --- | ||||||||||
| Q3<br><br><br>2025 | Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| INTERNATIONAL | |||||||||||
| Pipeline gas | |||||||||||
| USA | Mboe | 491 | 409 | 327 | 1,278 | 1,011 | |||||
| Trinidad & Tobago | Mboe | 242 | 2,205 | 2,289 | 4,863 | 6,528 | |||||
| Other^23^ | Mboe | 6 | 5 | - | 34 | - | |||||
| Total | Mboe | 739 | 2,619 | 2,616 | 6,175 | 7,539 | |||||
| Crude oil and condensate | |||||||||||
| Atlantis | Mbbl | 2,783 | 2,604 | 2,351 | 7,859 | 6,811 | |||||
| Mad Dog | Mbbl | 2,310 | 2,470 | 2,363 | 7,357 | 8,072 | |||||
| Shenzi | Mbbl | 2,088 | 2,021 | 2,047 | 6,431 | 6,785 | |||||
| Trinidad & Tobago | Mbbl | 13 | 93 | 143 | 205 | 363 | |||||
| Sangomar | Mbbl | 7,516 | 7,396 | 5,902 | 21,922 | 6,442 | |||||
| Other^23^ | Mbbl | 5 | - | 81 | 5 | 243 | |||||
| Total | Mboe | 14,715 | 14,584 | 12,887 | 43,779 | 28,716 | |||||
| NGL | |||||||||||
| USA | Mbbl | 442 | 398 | 515 | 1,238 | 1,263 | |||||
| Other^23^ | Mbbl | 3 | 3 | - | 18 | - | |||||
| Total | Mboe | 445 | 401 | 515 | 1,256 | 1,263 | |||||
| Total International | Mboe | **** | 15,899 | **** | 17,604 | **** | 16,018 | **** | 51,210 | **** | 37,518 |
| Mboe/d | **** | 173 | **** | 193 | **** | 174 | **** | 188 | **** | 137 | |
| Total Production | Mboe | **** | 50,754 | **** | 50,056 | **** | 53,084 | **** | 149,925 | **** | 142,416 |
| Mboe/d | **** | 552 | **** | 550 | **** | 577 | **** | 549 | **** | 520 | |
| ^23^ | Overriding royalty interests held in the USA for several producing wells. | ||||||||||
| --- | --- | ||||||||||
| 10 | Third quarter report for period ended 30 September 2025 | ||||||||||
| --- | --- |
Product sales
| Q3 2025 | Q2 2025 | Q3 2024 | YTD 2025 | YTD 2024 | |||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Gas | MMscf/d | 2,116 | 2,050 | 2,172 | 2,043 | 2,079 | |||||
| Liquids | Mbbl/d | 226 | 238 | 228 | 226 | 182 | |||||
| Total | Mboe/d | **** | 598 | **** | 598 | **** | 609 | **** | 585 | **** | 547 |
| Q3<br> <br>2025 | Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br> <br>2025 | YTD<br><br><br>2024 | |||||||
| AUSTRALIA | |||||||||||
| LNG | |||||||||||
| North West Shelf | Mboe | 4,743 | 5,059 | 7,353 | 16,689 | 22,442 | |||||
| Pluto | Mboe | 13,609 | 11,969 | 12,014 | 35,254 | 35,276 | |||||
| Wheatstone^24^ | Mboe | 1,623 | 3,346 | 3,345 | 7,186 | 8,104 | |||||
| Total | Mboe | 19,975 | 20,374 | 22,712 | 59,129 | 65,822 | |||||
| Pipeline gas | |||||||||||
| Bass Strait | Mboe | 4,070 | 3,620 | 4,163 | 10,989 | 10,241 | |||||
| Other^25^ | Mboe | 4,028 | 3,833 | 3,816 | 11,445 | 10,145 | |||||
| Total | Mboe | 8,098 | 7,453 | 7,979 | 22,434 | 20,386 | |||||
| Crude oil and condensate | |||||||||||
| North West Shelf | Mbbl | 1,194 | 616 | 1,253 | 3,039 | 4,371 | |||||
| Pluto | Mbbl | 1,338 | 650 | 858 | 2,693 | 2,781 | |||||
| Wheatstone | Mbbl | 417 | 651 | 360 | 1,402 | 1,355 | |||||
| Bass Strait | Mbbl | 531 | 599 | 662 | 1,664 | 1,530 | |||||
| Ngujima-Yin | Mbbl | 1,171 | 1,151 | 1,082 | 2,985 | 3,099 | |||||
| Okha | Mbbl | - | 1,256 | 618 | 1,256 | 1,808 | |||||
| Macedon & Pyrenees | Mbbl | 496 | 498 | 498 | 1,493 | 994 | |||||
| Total | Mboe | 5,147 | 5,421 | 5,331 | 14,532 | 15,938 | |||||
| NGL | |||||||||||
| North West Shelf | Mbbl | 430 | - | 249 | 907 | 770 | |||||
| Pluto | Mbbl | 105 | - | 52 | 215 | 156 | |||||
| Bass Strait | Mbbl | 374 | 1,010 | 1,142 | 1,610 | 2,288 | |||||
| Total | Mboe | 909 | 1,010 | 1,443 | 2,732 | 3,214 | |||||
| Total Australia | Mboe | **** | 34,129 | **** | 34,258 | **** | 37,465 | **** | 98,827 | **** | 105,360 |
| Mboe/d | **** | 371 | **** | 376 | **** | 407 | **** | 362 | **** | 385 | |
| ^24^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.29<br>MMboe in Q3 2024 and 0.20 MMboe in YTD 2024. Restatement allows for revenue presented in this quarterly report to reconcile to operating revenue, the IFRS measure presented in Woodside Financial Statements. | ||||||||||
| --- | --- | ||||||||||
| ^25^ | Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.<br> | ||||||||||
| --- | --- | ||||||||||
| 11 | Third quarter report for period ended 30 September 2025 | ||||||||||
| --- | --- | ||||||||||
| Q3<br><br><br>2025 | Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- | --- |
| INTERNATIONAL | |||||||||||
| Pipeline gas | |||||||||||
| USA | Mboe | 344 | 324 | 286 | 962 | 908 | |||||
| Trinidad & Tobago | Mboe | 243 | 2,233 | 2,004 | 4,750 | 6,067 | |||||
| Other^26^ | Mboe | 4 | 4 | 2 | 12 | 13 | |||||
| Total | Mboe | 591 | 2,561 | 2,292 | 5,724 | 6,988 | |||||
| Crude oil and condensate | |||||||||||
| Atlantis | Mbbl | 2,801 | 2,606 | 2,436 | 7,901 | 6,875 | |||||
| Mad Dog | Mbbl | 2,310 | 2,485 | 2,489 | 7,415 | 8,158 | |||||
| Shenzi | Mbbl | 2,094 | 2,030 | 2,032 | 6,326 | 6,814 | |||||
| Trinidad & Tobago | Mbbl | 5 | 133 | 221 | 181 | 292 | |||||
| Sangomar | Mbbl | 6,833 | 7,505 | 6,070 | 20,859 | 6,070 | |||||
| Other^26^ | Mbbl | 47 | 47 | 45 | 151 | 164 | |||||
| Total | Mboe | 14,090 | 14,806 | 13,293 | 42,833 | 28,373 | |||||
| NGL | |||||||||||
| USA | Mbbl | 440 | 385 | 388 | 1,196 | 1,255 | |||||
| Other^26^ | Mbbl | 2 | 2 | 1 | 6 | 7 | |||||
| Total | Mboe | 442 | 387 | 389 | 1,202 | 1,262 | |||||
| Total International | Mboe | **** | 15,123 | **** | 17,754 | **** | 15,974 | **** | 49,759 | **** | 36,623 |
| Mboe/d | **** | 164 | **** | 195 | **** | 174 | **** | 182 | **** | 134 | |
| MARKETING^27^ | |||||||||||
| LNG | Mboe | 5,492 | 2,337 | 2,077 | 10,579 | 6,756 | |||||
| Liquids | Mboe | 249 | 64 | 555 | 417 | 1,163 | |||||
| Total | Mboe | 5,741 | 2,401 | 2,632 | 10,996 | 7,919 | |||||
| Total Marketing | Mboe | **** | 5,741 | **** | 2,401 | **** | 2,632 | **** | 10,996 | **** | 7,919 |
| Total sales | Mboe | **** | 54,993 | **** | 54,413 | **** | 56,071 | **** | 159,582 | **** | 149,902 |
| Mboe/d | **** | 598 | **** | 598 | **** | 609 | **** | 585 | **** | 547 | |
| ^26^ | Overriding royalty interests held in the USA for several producing wells. | ||||||||||
| --- | --- | ||||||||||
| ^27^ | Purchased volumes sourced from third parties. | ||||||||||
| --- | --- | ||||||||||
| 12 | Third quarter report for period ended 30 September 2025 | ||||||||||
| --- | --- |
Revenue (US$ million)
| Q3<br><br><br>2025 | Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | ||||||
|---|---|---|---|---|---|---|---|---|---|---|
| AUSTRALIA | ||||||||||
| North West Shelf | 323 | 295 | 520 | 1,153 | 1,636 | |||||
| Pluto | 1,000 | 827 | 920 | 2,539 | 2,556 | |||||
| Wheatstone^28^ | 135 | 255 | 265 | 589 | 676 | |||||
| Bass Strait | 265 | 283 | 344 | 776 | 814 | |||||
| Macedon | 44 | 52 | 48 | 148 | 147 | |||||
| Ngujima-Yin | 88 | 86 | 94 | 231 | 277 | |||||
| Okha | - | 90 | 51 | 90 | 147 | |||||
| Pyrenees | 37 | 39 | 44 | 120 | 88 | |||||
| TotalAustralia | **** | 1,892 | **** | 1,927 | **** | 2,286 | **** | 5,646 | **** | 6,341 |
| INTERNATIONAL | ||||||||||
| Atlantis | 196 | 181 | 194 | 568 | 558 | |||||
| Mad Dog | 150 | 161 | 192 | 501 | 645 | |||||
| Shenzi | 142 | 138 | 160 | 447 | 555 | |||||
| Trinidad & Tobago^29^ | 6 | 78 | 63 | 150 | 162 | |||||
| Sangomar | 477 | 510 | 464 | 1,468 | 464 | |||||
| Other^30^ | 2 | 4 | 3 | 9 | 13 | |||||
| TotalInternational | **** | 973 | **** | 1,072 | **** | 1,076 | **** | 3,143 | **** | 2,397 |
| Marketingrevenue^31^ | 452 | 232 | 285 | 996 | 777 | |||||
| Total salesrevenue^32^ | 3,317 | 3,231 | 3,647 | 9,785 | 9,515 | |||||
| Processing revenue | 39 | 35 | 54 | 148 | 167 | |||||
| Shipping and other<br>revenue | 3 | 9 | 6 | 16 | 13 | |||||
| Totalrevenue | **** | 3,359 | **** | 3,275 | **** | 3,707 | **** | 9,949 | **** | 9,695 |
| ^28^ | Restated to exclude periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of<br>$28 million in Q3 2024 and $14 million in YTD 2024. These amounts will be included within other income/(expenses) in the financial statements. Restatement allows for revenue presented in this quarterly report to reconcile to operating<br>revenue, the IFRS measure presented in Woodside Financial Statements. | |||||||||
| --- | --- | |||||||||
| ^29^ | Includes the impact of periodic adjustments related to the production sharing contract (PSC).<br> | |||||||||
| --- | --- | |||||||||
| ^30^ | Overriding royalty interests held in the USA for several producing wells. | |||||||||
| --- | --- | |||||||||
| ^31^ | Values include revenue generated from purchased LNG and Liquids volumes, as well as the marketing margin on the<br>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<br>these cargo swaps is recognised net in other income. | |||||||||
| --- | --- | |||||||||
| ^32^ | Referred to as ‘Revenue from sale of hydrocarbons’ in Woodside financial statements. Total sales<br>revenue excludes all hedging impacts. | |||||||||
| --- | --- | |||||||||
| 13 | Third quarter report for period ended 30 September 2025 | |||||||||
| --- | --- |
Realised prices
| Units | Q2<br><br><br>2025 | Q3<br><br><br>2024 | Units | Q2<br><br><br>2025 | Q3<br><br><br>2024 | |||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| LNG produced | /MMBtu | 9.5 | 9.8 | 10.8 | /boe | 60 | 62 | 68 | ||||
| LNG traded^33^ | /MMBtu | 11.2 | 11.4 | 11.2 | /boe | 71 | 72 | 71 | ||||
| Pipeline gas | /boe | 38 | 36 | 38 | ||||||||
| Oil and condensate | /bbl | 68 | 68 | 78 | /boe | 68 | 68 | 78 | ||||
| NGL | /bbl | 41 | 43 | 48 | /boe | 41 | 43 | 48 | ||||
| Liquids traded^33^ | /bbl | 60 | 68 | 60 | /boe | 60 | 68 | 60 | ||||
| Average realised price for pipeline gas: | ||||||||||||
| Western Australia | A/GJ | 6.8 | 6.8 | 6.5 | ||||||||
| East Coast Australia | A/GJ | 12.9 | 13.4 | 14.2 | ||||||||
| International | /Mcf | 4.2 | 4.7 | 4.3 | ||||||||
| Average<br>realised price | /boe | 60 | 59 | 65 | ||||||||
| Dated Brent | /bbl | 69 | 68 | 80 | ||||||||
| JCC (lagged three months) | /bbl | 75 | 79 | 88 | ||||||||
| WTI | /bbl | 65 | 64 | 75 | ||||||||
| JKM | /MMBtu | 12.5 | 12.5 | 12.4 | ||||||||
| TTF | /MMBtu | 11.7 | 12.2 | 11.2 |
All values are in US Dollars.
Average realised price increased 2% from the prior quarter reflecting higher Dated Brent and West Texas Intermediate (WTI).
| ^33^ | Excludes any additional benefit attributed to produced volumes through third-party trading activities.<br> |
|---|---|
| 14 | Third quarter report for period ended 30 September 2025 |
| --- | --- |
Capital expenditure (US$ million)
| Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Evaluation capitalised34 | 8 | 17 | 6 | 37 | 60 | |||||||
| Property plant & equipment | 1,032 | 828 | 1,076 | 2,749 | 3,301 | |||||||
| Other<br>35 | 7 | 23 | 51 | 34 | 162 | |||||||
| Capital expenditure excluding<br>Louisiana LNG | 1,047 | **** | **** | 868 | **** | **** | 1,133 | **** | 2,820 | **** | **** | 3,523 |
| Louisiana LNG36 | 498 | 1,754 | - | 3,153 | - | |||||||
| Cash contribution from Stonepeak37 | (222 | ) | (1,870 | ) | - | (2,092 | ) | - | ||||
| Total Louisiana<br>LNG | 276 | **** | **** | (116 | ) | **** | - | **** | 1,061 | **** | **** | - |
| Total capital<br>expenditure | 1,323 | **** | **** | 752 | **** | **** | 1,133 | **** | 3,881 | **** | **** | 3,523 |
| Acquisitions38 | - | **** | **** | - | **** | **** | 1,900 | **** | - | **** | **** | 1,900 |
| Total | 1,323 | **** | **** | 752 | **** | **** | 3,033 | **** | 3,881 | **** | **** | 5,423 |
| Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||||
| Scarborough | 361 | 333 | 438 | 1,016 | 1,575 | |||||||
| Trion | 291 | 92 | 225 | 698 | 459 | |||||||
| Sangomar | - | 10 | 73 | 17 | 489 | |||||||
| Other | 395 | 433 | 397 | 1,089 | 1,000 | |||||||
| Capital expenditure excluding<br>Louisiana LNG | 1,047 | **** | **** | 868 | **** | **** | 1,133 | **** | 2,820 | **** | **** | 3,523 |
| Other expenditure (US million) | ||||||||||||
| Q2<br><br><br>2025 | Q3<br><br><br>2024 | YTD<br><br><br>2025 | YTD<br><br><br>2024 | |||||||||
| Exploration capitalised34,39 | 17 | - | - | 22 | 22 | |||||||
| Exploration and evaluation<br>expensed40 | 46 | 46 | 90 | 127 | 190 | |||||||
| Permit amortisation | 2 | - | 2 | 5 | 8 | |||||||
| Total | 65 | **** | **** | 46 | **** | **** | 92 | **** | 154 | **** | **** | 220 |
| Trading costs | 445 | **** | **** | 178 | **** | **** | 132 | **** | 855 | **** | **** | 405 |
All values are in US Dollars.
| ^34^ | Project final investment decisions result in amounts of previously capitalised exploration and evaluation<br>expense (from current and prior years) being transferred to property plant & equipment. This table does not reflect the impact of such transfers. |
|---|---|
| ^35^ | Other primarily incorporates corporate spend including SAP build costs, other investments and other capital<br>expenditure. |
| --- | --- |
| ^36^ | Capital expenditure for Louisiana LNG is presented at 100% working interest equity. |
| --- | --- |
| ^37^ | Cash contributions received from Stonepeak represent its share of the project’s capital expenditure since<br>the effective date of 1 January 2025. |
| --- | --- |
| ^38^ | Acquisition of OCI’s Clean Ammonia Project in Beaumont, Texas |
| --- | --- |
| ^39^ | Exploration capitalised has been reclassified from capital expenditure to other expenditure. Exploration<br>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. |
| --- | --- |
| ^40^ | Includes seismic and general permit activities and other exploration costs. |
| --- | --- |
| 15 | Third quarter report for period ended 30 September 2025 |
| --- | --- |
Exploration or appraisal wells drilled
| Region | Permit area | Well | Target | Interest (%) | Spud date | Water depth (m) | Planned well depth (m)^41^ | Remarks |
|---|---|---|---|---|---|---|---|---|
| UnitedStates | GC 680 | Bandit-1 | Oil | 17.5%<br>Non-operator | 2 September<br>2025 | 1,555 | 10,811 | Drilling |
Permits and licences
Key changes to permit and licence holdings during the quarter ended 30 September 2025 are noted below.
| Region | Permits or licence areas | Change in interest (%) | Current interest (%) | Remarks |
|---|---|---|---|---|
| GC 679, GC 768 | (14.4%) | 17.5% | Licence assignment^42^ | |
| GC 680, GC 723, GC 724 | 17.5% | 17.5% | Licence assignment^42^ | |
| MC 411, MC 412 | (25%) | — | Licence expired | |
| United States | GC 80, GC 123 | (75%) | — | Licence expired |
| GB 678, GC 663, GC 664, GB 630, GB 676, GB 677, GB 762, GB 805, GB 806, GB 851, GB 852, GB 895, GB 672, GB 716, GB 760 | (100%) | — | Licence relinquished | |
| EB 566, EB 567, EB 610, EB 611 | (70%) | — | Licence relinquished | |
| ^41^ | Well depths are referenced to the rig rotary table. | |||
| --- | --- | |||
| ^42^ | Awaiting Bureau of Ocean Energy Management approval. | |||
| --- | --- | |||
| 16 | Third quarter report for period ended 30 September 2025 | |||
| --- | --- |
Production rates
Average daily production rates (100% project) for the quarter ended 30 September 2025:
| Woodsideshare^43^ | Production rate(100% project,Mboe/d) | Remarks | ||||||
|---|---|---|---|---|---|---|---|---|
| Sep2025 | Jun2025 | |||||||
| AUSTRALIA | ||||||||
| NWS Project | ||||||||
| LNG | 29.33 | % | 218 | 202 | Production was higher due to planned maintenance in prior quarter. | |||
| Crude oil and condensate | 29.53 | % | 40 | 34 | ||||
| NGL | 29.58 | % | 9 | 8 | ||||
| Pluto LNG | ||||||||
| LNG | 90.00 | % | 123 | 115 | Production was higher due to increased reliability. | |||
| Crude oil and condensate | 90.00 | % | 11 | 10 | ||||
| Pluto-KGPInterconnector | ||||||||
| LNG | 100.00 | % | 23 | 19 | Production was higher due to greater processing capacity at the Karratha Gas Plant. | |||
| Crude oil and condensate | 100.00 | % | 1 | 1 | ||||
| NGL | 100.00 | % | 1 | 1 | ||||
| Wheatstone^44^ | ||||||||
| LNG | 12.40 | % | 235 | 231 | Production was higher due to increased seasonal plant capacity. | |||
| Crude oil and condensate | 16.31 | % | 31 | 31 | ||||
| Bass Strait | ||||||||
| Pipeline gas | 45.48 | % | 94 | 84 | Production was higher due to increased seasonal demand. | |||
| Crude oil and condensate | 45.29 | % | 12 | 11 | ||||
| NGL | 46.47 | % | 20 | 18 | ||||
| Australia Oil | ||||||||
| Ngujima-Yin | 60.00 | % | 17 | 20 | Production was lower due to reliability. | |||
| Okha | 50.00 | % | 13 | 13 | ||||
| Pyrenees | 63.34 | % | 6 | 9 | ||||
| Other | ||||||||
| Pipeline gas^45^ | 43 | 44 | ||||||
| ^43^ | Woodside share reflects the net realised interest for the period. | |||||||
| --- | --- | |||||||
| ^44^ | The Wheatstone asset processes gas from several offshore gas fields, including the Julimar and Brunello fields,<br>for which Woodside has a 65% participating interest and is the operator. | |||||||
| --- | --- | |||||||
| ^45^ | Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.<br> | |||||||
| --- | --- | |||||||
| 17 | Third quarter report for period ended 30 September 2025 | |||||||
| --- | --- | |||||||
| Woodsideshare^46^ | Production rate(100% project,Mboe/d) | Remarks | ||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| Sep<br><br><br>2025 | Jun<br><br><br>2025 | |||||||
| INTERNATIONAL | ||||||||
| Atlantis | ||||||||
| Crude oil and condensate | 38.50 | % | 79 | 74 | Production was higher with new well online. | |||
| NGL | 38.50 | % | 7 | 6 | ||||
| Pipeline gas | 38.50 | % | 11 | 8 | ||||
| Mad Dog | ||||||||
| Crude oil and condensate | 20.86 | % | 120 | 130 | Production was lower due to planned Southwest Extension tie in works. | |||
| NGL | 20.86 | % | 4 | 4 | ||||
| Pipeline gas | 20.86 | % | 2 | 2 | ||||
| Shenzi | ||||||||
| Crude oil and condensate | 64.57 | % | 35 | 34 | ||||
| NGL | 64.63 | % | 2 | 2 | ||||
| Pipeline gas | 64.60 | % | 1 | 1 | ||||
| Trinidad & Tobago | ||||||||
| Crude oil and condensate | 79.14 | %^47^ | – | 1 | Greater Angostura divestment completed in July. | |||
| Pipeline gas | 47.05 | %^47^ | 6 | 51 | ||||
| Sangomar | ||||||||
| Crude oil | 82.52 | %^47^ | 99 | 101 | ||||
| ^46^ | Woodside share reflects the net realised interest for the period. | |||||||
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| ^47^ | Operations governed by production sharing contracts. | |||||||
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| 18 | Third quarter report for period ended 30 September 2025 | |||||||
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Disclaimer and important notice
Forward looking statements
This report contains forward-looking statements with respect to Woodside’s business and operations, 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, potential investment decisions, development, completion and execution of Woodside’s projects, expectations regarding future capital expenditures, 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, income, expenses, costs, losses, capital and exploration expenditure, gas hub exposure and expectations regarding the achievement of Woodside’s net equity Scope 1 and 2 greenhouse gas emissions reduction 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 ‘guidance’, ‘foresee’, ‘likely’, ‘potential’, ‘anticipate’, ‘believe’, ‘aim’, ‘aspire’, ‘estimate’, ‘expect’, intend’, ‘may’, ‘target’, ‘plan’, ‘strategy’, ‘forecast’, ‘outlook’, ‘project’, ‘schedule’, ‘will’, ‘should’, ‘seek’, and other similar words or expressions. Similarly, statements that describe the objectives, plans, goals or expectations of Woodside are forward-looking statements.
Forward-looking statements in this report are not 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 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 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, climate related transition and physical risks, changes in accounting, standards, economic and financial markets conditions in various countries and regions, 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, and the effect of future regulatory or legislative actions on Woodside or the industries in which it operates, including potential changes to tax laws, and 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” 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.
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, 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 report, either to make them conform to actual results or as a result of new information, future events, changes in Woodside’s expectations or otherwise.
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. 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. Past performance (including historical financial and operational information) is given for illustrative purposes only. It should not be relied on as, and is not necessarily, a reliable indicator of future performance, including future security prices.
| 19 | Third quarter report for period ended 30 September 2025 |
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Other important information
All figures are Woodside share for the quarter ending 30 September 2025, unless otherwise stated.
All references to dollars, cents or $ in this report 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).
Notes to petroleum reserves and resources
| 1. | The petroleum resource estimates are quoted as at the effective date of 30 September 2025, net Woodside<br>share. For details of Woodside’s year end 2024 reserves position, see the Reserves and Resources Statement included in the 2024 Annual Report. US Investors should refer to “Additional information for US investors concerning reserves and<br>resources estimates” below. |
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| 2. | All numbers are internal estimates produced by Woodside. Estimates of reserves and contingent resources should<br>be regarded only as estimates that may change over time as additional information becomes available. |
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| 3. | The reference point is defined as the outlet of the floating production storage and offloading facility (FPSO).<br> |
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| 4. | ‘Reserves’ are estimated quantities of petroleum that have been demonstrated to be producible from<br>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<br>consumed in operations. Woodside estimates and reports its proved reserves in accordance with SEC regulations which are also compliant with the 2018 Society of Petroleum Engineers (SPE)/World Petroleum Council (WPC)/American Association of Petroleum<br>Geologists (AAPG)/Society of Petroleum Evaluation Engineers (SPEE) Petroleum Resources Management System (PRMS) (SPE-PRMS) guidelines. SEC-compliant proved reserves<br>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<br>prices based on the average of first of month prices during the 12-month period in the reporting company’s fiscal year. Woodside estimates and reports its proved plus probable reserves in accordance with<br>SPE-PRMS guidelines which are not compliant with SEC regulations. |
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| 5. | Assessment of the economic value in support of an SPE-PRMS<br>(2018) 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<br>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. |
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| 6. | Woodside uses both deterministic and probabilistic methods for the estimation of reserves and contingent<br>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<br>4-10(a) of Regulation S-X. |
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| 7. | ‘MMboe’ means millions (10^6^) of barrels<br>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<br>(101.325 kPa) and 60 degrees Fahrenheit (15.56 degrees Celsius). |
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| 8. | ‘Proved reserves’ are those quantities of crude oil, condensate, natural gas and NGLs that, by<br>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<br>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. |
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| 9. | ‘Undeveloped reserves’ are those reserves for which wells and facilities have not been installed or<br>executed but are expected to be recovered through future significant investments. |
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| 10. | ‘Probable reserves’ are those reserves which analysis of geological and engineering data suggests<br>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<br>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.<br> |
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| 11. | The estimates of petroleum reserves and contingent resources are based on and fairly represent information and<br>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<br>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<br>27 years of relevant experience. |
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| 20 | Third quarter report for period ended 30 September 2025 |
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Additional information for US investors concerning resource estimates
Woodside is an Australian company with securities listed on the Australian Securities Exchange and the New York Stock Exchange. As noted above, Woodside estimates and reports its proved reserves in accordance with SEC regulations, which are also compliant with SPE-PRMS guidelines, and estimates and reports its proved plus probable reserves and 2C contingent resources in accordance with SPE-PRMS guidelines. Woodside reports all 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 announcement, 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 terms 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 types of estimates do not represent, and are not intended to represent, any category of reserves based on SEC definitions, and may differ from and may not be comparable to the same or similarly-named measures used by other companies. 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. The Reserves Statement presenting Woodside’s proved oil and gas reserves in accordance with the regulations of the SEC is filed with the SEC as part of Woodside’s annual report on Form 20-F. US investors are urged to consider closely the disclosures in Woodside’s most recent Annual Report on Form 20-F filed with the SEC and available on the Woodside website at https://www.woodside.com/investors/reports-investor-briefings and its other filings with the SEC, which are available at www.sec.gov.
| Glossary, units of measure and conversion factors |
|---|
Refer to the Glossary in the Annual Report 2024 for definitions, including carbon related definitions.
| Product | Unit | Conversion factor |
|---|---|---|
| Natural<br>gas | 5,700 scf | 1 boe |
| Condensate | 1 bbl | 1 boe |
| Oil | 1 bbl | 1 boe |
| Natural<br>gas liquids | 1 bbl | 1 boe |
| Facility | Unit | LNG Conversion factor |
| Karratha<br>Gas Plant | 1 tonne | 8.08 boe |
| Pluto<br>LNG Gas Plant | 1 tonne | 8.34 boe |
| Wheatstone | 1 tonne | 8.27 boe |
| 21 | Third quarter report for period ended 30 September 2025 | |
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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.
| Term | Definition |
|---|---|
| bbl | barrel |
| bcf | billion cubic feet of gas |
| boe | barrel of oil equivalent |
| GJ | gigajoule |
| 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 |
| Glossary | |
| --- |
Refer to the Glossary in the Annual Report for definitions, including carbon related definitions.
| 22 | Third quarter report for period ended 30 September 2025 |
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