Woodside Energy Q2 2026: Revenue jumps 28% as Sangomar delivers and Scarborough approaches first LNG

Woodside Energy Group Ltd (ASX: WDS, NYSE: WDS) has released its second-quarter report for the period ended 30 June 2026, posting operating revenue of $4,185 million, up 28 per cent on the prior quarter, alongside an average realised price of $85 per barrel of oil equivalent. The Perth-based operator delivered the quarter under new Chief Executive Officer Liz Westcott while advancing three growth projects, the Scarborough Energy Project to 98 per cent completion, Trion to 64 per cent and Louisiana LNG to 28 per cent. Woodside Energy Group also exercised its pre-emption right over PetroChina International Investment (Australia) Pty Ltd’s 10.67 per cent stake in the Browse Joint Venture and completed the transfer of Gippsland Basin operatorship from ExxonMobil. The central tension for investors is whether operational reliability across the base portfolio and the near-term Scarborough milestone can offset a $400 million net hedge cash outflow, a 21 per cent gearing print, and $8-9 billion of concurrent growth capex through 2029.

Why did Woodside Energy Group’s operating revenue climb 28 per cent even as production fell 9 per cent quarter-on-quarter?

The headline production line went the wrong way. Woodside Energy Group delivered 41.3 million barrels of oil equivalent for the quarter, or 454 thousand barrels of oil equivalent per day, down 9 per cent on Q1 2026 and down 18 per cent on Q2 2025. The decline reflected planned maintenance at Pluto Train 1 and recovery from Severe Tropical Cyclone Narelle, which had affected Wheatstone and the Pyrenees FPSO earlier in the year. Despite that, operating revenue rose to $4,185 million, up 28 per cent quarter-on-quarter and 28 per cent year-on-year, because realised prices moved sharply higher. The average realised price of $85 per barrel of oil equivalent was 35 per cent above the $63 recorded in Q1 2026 and 44 per cent above Q2 2025.

The underlying price story was broadly supportive. Dated Brent averaged $105 per barrel over the quarter versus $81 in Q1. Japan Korea Marker LNG rose to $17.5 per million British thermal units from $10.4, while Title Transfer Facility gas hub prices reached $16.4 per million British thermal units from $10.8. Woodside Energy Group’s LNG-produced realised price came in at $10.5 per million British thermal units, its LNG-traded price at $15.2, and oil and condensate at $107 per barrel. The company also noted that price lags from Q2 will be realised in Q3, meaning some of the higher pricing environment will feed through with a lag.

Why does Sangomar’s 99.3 per cent reliability at near-nameplate production matter more than the headline production dip?

Sangomar, offshore Senegal, is the single most important operational data point in this quarter. Woodside Energy Group reported reliability of 99.3 per cent, with average daily production of 99 thousand barrels per day on a 100 per cent basis, of which 86 thousand barrels per day was Woodside’s share. That production share reflects accelerated recovery of pre-final investment decision costs under the production sharing contract entitlement, an effect driven by high oil prices.

The company disclosed something more strategically important. Reservoir performance in the lower S500 reservoirs is continuing to exceed expectations, driven by greater than anticipated aquifer pressure support. Combined with well and network optimisation, that has extended the initial plateau and partially mitigated the decline rates now emerging. This matters because Sangomar was Woodside Energy Group’s most watched development transition after the merger with BHP Petroleum reshaped the international portfolio. Evaluation of a potential Sangomar Phase 2 development targeting the upper S400 reservoirs is continuing, with engagements underway with Petrosen and the Senegalese government. Sangomar’s YTD 2026 crude oil production of 15,006 thousand barrels is already tracking ahead of the 14,406 thousand barrels booked in YTD 2025, on a smaller quarterly volume base than Q2 2025, which underscores the strength of the plateau.

Alongside Sangomar, Shenzi in the Gulf of America delivered 99.2 per cent reliability, Pluto LNG achieved 97.6 per cent, and the North West Shelf Project LNG delivered 97.8 per cent. Those reliability numbers matter because they translate directly into the narrower 2026 production guidance range of 174-185 million barrels of oil equivalent, from a prior 172-186 million.

How close is the Scarborough Energy Project to first LNG cargo, and what changed with first gas from the reservoir?

The Scarborough Energy Project reached 98 per cent completion at the end of the quarter and remains on budget, with first LNG cargo tracked for Q4 2026. Two events subsequent to the period materially reduce the residual technical risk. The Floating Production Unit achieved ready for start-up status. First gas was also achieved from the Scarborough reservoir, and the trunkline reached ready for start-up status, enabling commencement of pressurisation from the Floating Production Unit through to the onshore plant.

At the Pluto Train 2 site, gas turbine generator synchronisation with the Pluto site power grid has been completed, and three of the six liquefaction compressors have completed mechanical runs. The final module for the Pluto Train 1 modifications shipped from a fabrication yard in Thailand and, subsequent to the quarter, arrived at Pluto. Multiple integration scopes and tie-ins were completed during the Pluto LNG Train 1 planned maintenance in May 2026. The planned maintenance itself was delivered on schedule and budget, which the company flagged as a critical milestone for Scarborough integration.

Investors watching Woodside Energy Group have viewed Scarborough as the single largest execution overhang since final investment decision. A slip in the Q4 2026 first LNG target would materially affect 2027 cash flow and the pace at which the 2029 Louisiana LNG capex bulge is offset by Scarborough cash generation. On the current disclosures, that risk has continued to narrow.

What does the Trion and Louisiana LNG progress signal about Woodside’s growth pipeline through 2029?

Trion, offshore Mexico, reached 64 per cent completion, remains on budget, and continues to target first oil in 2028. Three wells of the 24-well drilling programme have been drilled. Subsea equipment deliveries to Mexico have commenced, the Floating Production Unit topside modules have been lifted onto the hull, and the disconnectable turret mooring buoy has been fabricated and tested. Trion adds a discrete oil-linked growth leg to a portfolio that increasingly leans on gas and LNG.

Louisiana LNG remains on budget at 28 per cent complete overall, with Train 1 at 35 per cent, Train 2 at 25 per cent, and Train 3 at 18 per cent. First LNG is targeted for 2029. Woodside Energy Group awarded a services contract valued at more than $300 million for construction of four tug boats, taking committed spend with Louisiana suppliers beyond $1 billion. Five long-term charter parties for LNG carriers commencing in 2029 have been signed to support the project.

There is a supply-chain risk worth flagging. Ongoing disruptions through the Strait of Hormuz are challenging structural steel delivery from Bechtel’s fabrication facility in the United Arab Emirates. Woodside Energy Group said it is implementing mitigation measures including alternative logistics routes and additional fabrication sources to maintain planned construction schedules beyond 2026. This is the most direct read-through so far in the disclosure to the ongoing Middle East disruption affecting long-lead engineering, procurement and construction projects.

How does the Browse pre-emption from PetroChina reshape Woodside’s long-dated LNG development concept?

In June, Woodside Energy Group exercised its pre-emption right to acquire PetroChina International Investment (Australia) Pty Ltd’s 10.67 per cent participating interest in the Browse Joint Venture. Completion is subject to customary conditions precedent including regulatory approvals. On completion, Woodside Energy Group’s stake will rise to 41.27 per cent. The terms include a payment of $225 million on completion, reimbursement of PetroChina’s Browse Joint Venture cash call contributions from 30 June 2025 to completion date, and a contingent payment of $175 million payable on a final investment decision covering development of all of the Brecknock, Calliance and Torosa fields on or before 30 June 2032.

Subsequent to the period, the Western Australian State Government granted State Significant Project status under the Lead Agency Framework for the Browse to North West Shelf Project. A revised Browse Carbon Capture and Storage environmental referral has been submitted to the Commonwealth regulator, and the Federal Environment Minister has determined that the Browse Carbon Capture and Storage Project can be assessed wholly under the Environment Protection and Biodiversity Conservation Act 1999. Neither ruling is a development approval, but both are procedural gates that had to be cleared for the project to progress. Browse remains a long-dated concept, and management has flagged its potential to deliver long-term economic benefits for Australia. Investors should still treat the contingent $175 million payment as reflective of the remaining distance to a final investment decision.

Why is Woodside Energy Group’s balance sheet showing 21 per cent gearing despite $8.2 billion in liquidity?

Liquidity at the end of the quarter stood at approximately $8,200 million after the fully franked dividend paid in March. Net debt, including lease liabilities, was approximately $9,300 million, with gearing of approximately 21 per cent. Woodside Energy Group repaid a $600 million Syndicated Term Loan on 29 June 2026, approximately six months prior to maturity.

Three specific items drove the net debt and gearing profile. Around $600 million of lease liabilities were recognised in the first half of 2026 for the Woodside Bilangara LNG vessel and Trion construction-related vessels. Hedge settlements produced a net cash outflow of approximately $400 million during the quarter. Higher pricing drove roughly a $100 million increase in trade receivables expected to be collected in July.

For a company simultaneously executing Scarborough completion, Trion drilling and Louisiana LNG construction, 21 per cent gearing is a reasonable working range. Capital expenditure and acquisitions totalled $784 million in Q2 2026 and $2,107 million year-to-date, with full-year capex guidance held at $4,000-4,500 million. The Louisiana LNG line remains net negative in the quarter after cash contributions from Stonepeak and Williams, which is by design under the sell-down structure agreed in 2025. Investors should watch how quickly gearing normalises once Scarborough begins delivering cash flow from Q4 2026 and how much of the peak capex load falls within existing partner cash-call arrangements.

What do the hedge losses and the Perdaman embedded derivative tell us about Woodside Energy Group’s earnings quality?

Approximately 62 per cent of the 30 million barrels of oil equivalent of 2026 oil-linked production previously hedged, at an average price of $74.23 per barrel, had been cash settled by 30 June 2026. No additional oil-linked corporate hedges were entered into during the quarter, and the 2027 hedge position is unchanged. Hedge settlements produced a net cash outflow of approximately $400 million during the quarter.

Woodside Energy Group flagged an important timing effect. Cash settlements on oil-linked hedges occur in advance of the related profit and loss impact, so a temporary difference has opened between cash flows and reported earnings. An estimated pre-tax loss of $70 million, primarily relating to Corpus Christi LNG hedges and foreign exchange hedges, was recognised in the period. The losses relating to oil-linked hedges cash-settled during the quarter are expected to be recognised in Q3, offset by higher revenue from the realisation of Q2 price lags.

Separately, the fair value of the embedded commodity derivative in the Perdaman gas sale and purchase contract, tied to urea prices with Title Transfer Facility used as a proxy, produced an unrealised pre-tax loss of approximately $135 million expected to be recognised through other expense. Impairment losses of approximately $160-200 million are also expected, relating to the Calypso Project and other items, and are excluded from underlying net profit after tax under Woodside Energy Group’s line-item guidance. A statutory Petroleum Resource Rent Tax adjustment of approximately $600 million pre-income tax, driven by the higher pricing environment, will flow through as a Pluto deferred tax asset benefit.

The half-year print on 25 August 2026 will show how much of the headline realised-price uplift translates into underlying earnings once the hedge, Perdaman and impairment effects are stripped out.

How is Woodside repositioning its Australian portfolio through the Chevron swap, Gippsland Basin operatorship and Alcoa gas deal?

Three portfolio moves ran in parallel during the quarter. Woodside Energy Group entered a sale and purchase agreement with Alcoa for the supply of 31.1 petajoules of domestic gas over the period 2027 to 2030, part of a wider 47.5 petajoule package into the Western Australian market. A further 38.9 petajoule package has been signed into the East Coast market for 2026 to 2028.

Subsequent to the period, on 1 July 2026, Woodside Energy Group completed the transfer of operatorship for the Gippsland Basin assets from ExxonMobil. This adds an operated legacy gas business supplying the Australian east coast to a portfolio that has otherwise been increasingly weighted to international deepwater and Australian LNG. The Turrum Phase 3 drilling programme has completed all five wells and is now in completion activities, with first production targeted for H1 2027.

Completion of the asset swap with Chevron is targeted for Q4 2026. That transaction is intended to streamline operations and consolidate focus on Woodside Energy Group’s operated LNG assets. Together, the three moves reduce non-operated exposure, extend the domestic gas book and consolidate Australian operatorship at a time when the state and federal regulatory framework for east coast gas is a live policy issue.

What is the market reaction telling us against Woodside Energy Group’s A$32.74 close, 25 per cent one-year gain and the 25 August half-year print?

Woodside Energy Group shares closed at A$32.74 on the Australian Securities Exchange on Wednesday 29 July 2026, up 1.39 per cent on the results day from A$32.29 the prior close, on a day range of A$32.15 to A$32.82. Volume of approximately 6 million shares turned over around A$199 million. The stock has traded within a 52-week range of A$21.96 to A$35.82, is up approximately 12 per cent over the past month and approximately 25 per cent over the past year. The share-price movement on results day coincided with the announcement rather than proving underlying investor conviction, and the more meaningful market test will follow the 25 August half-year report.

Chair Richard Goyder AO has indicated his intention to retire at or before the end of his current term in 2027. The Woodside Energy Group Board has begun a formal chair succession process, led by independent Non-executive Director Swee Chen Goh. A structured review announced with the Q1 2026 results is progressing and will receive a further update alongside the half-year print. Both processes remain governance context rather than material near-term events.

What should investors track as Woodside Energy Group brings Scarborough to first LNG cargo and delivers the 25 August 2026 half-year print?

• Woodside Energy Group posted Q2 2026 operating revenue of $4,185 million, up 28 per cent on Q1 2026 and 28 per cent on Q2 2025, on a realised price of $85 per barrel of oil equivalent that was 35 per cent above the prior quarter.
• Production came in at 41.3 million barrels of oil equivalent, down 9 per cent quarter-on-quarter, reflecting planned Pluto Train 1 maintenance and cyclone recovery, while 2026 full-year production guidance was narrowed to 174-185 million barrels of oil equivalent.
• Sangomar delivered reliability of 99.3 per cent at near-nameplate production of 99 thousand barrels per day (100 per cent basis), with reservoir performance continuing to exceed expectations in the lower S500 reservoirs.
• The Scarborough Energy Project reached 98 per cent completion with first gas achieved from the reservoir subsequent to the period, keeping first LNG cargo on track for Q4 2026 and materially reducing residual execution risk.
• Trion progressed to 64 per cent complete with first oil targeted in 2028, and Louisiana LNG reached 28 per cent complete with Train 1 at 35 per cent and first LNG targeted in 2029, though Strait of Hormuz disruption is challenging structural steel delivery from the United Arab Emirates.
• Woodside Energy Group exercised its pre-emption right over PetroChina’s 10.67 per cent interest in the Browse Joint Venture, taking its stake to 41.27 per cent on completion, with a $225 million completion payment and $175 million contingent on final investment decision by 30 June 2032.
• Liquidity of approximately $8.2 billion, net debt of approximately $9.3 billion and gearing of approximately 21 per cent reflect a peak growth-capex phase, with the $600 million Syndicated Term Loan repaid six months early.
• A net hedge cash outflow of approximately $400 million and an unrealised $135 million Perdaman embedded derivative loss weigh on headline cash and reported earnings, though the oil-linked hedge losses are expected to be offset in Q3 by realisation of Q2 price lags.
• The Alcoa 31.1 petajoule Western Australian domestic gas deal, the completed Gippsland Basin operatorship transfer from ExxonMobil, and the targeted Q4 2026 Chevron asset swap together reposition Woodside Energy Group toward operated LNG and a stronger domestic gas book.
• The 25 August 2026 half-year results will be the next measurable test of underlying earnings quality once hedge, Perdaman and Calypso impairment effects are stripped out, alongside the Q4 2026 Scarborough first LNG cargo as the single largest near-term operational catalyst.