Advancing growth and delivering reliable energy
Performance highlights
-- Sangomar, Shenzi, North West Shelf Project and Pluto LNG all delivered outstanding reliability at or above 99%. -- Achieved an average realised quarterly price of $63/boe, up 11% from Q4 2025 reflecting benefits from market prices. -- Delivered quarterly production volumes of 45.2 MMboe (502 Mboe/d), down 8% from Q4 2025 due to seasonal weather events.
Project highlights
-- The Scarborough Energy Project was 96% complete and remains on budget
and on track for first LNG cargo in Q4 2026.
-- The Scarborough Floating Production Unit (FPU) completed hook-up and
commenced topside commissioning following its arrival in Australia.
-- Beaumont New Ammonia achieved first ammonia cargo in February, with
Woodside assuming operational control in March.
-- The Trion Project progressed to 56% complete and remains on budget and
targeting first oil in 2028.
-- The foundation phase of Louisiana LNG Project remains on budget and on
schedule. The project was 24% complete with Train 1 31% complete. The
project is targeting first LNG in 2029.
Business and portfolio highlights
-- Liz Westcott appointed as CEO and Managing Director.
-- Safe restoration of Western Australian operations following Severe
Tropical Cyclone Mitchell and Severe Tropical Cyclone Narelle.
PERTH, Australia--(BUSINESS WIRE)--April 28, 2026--
Woodside Energy Group (ASX: WDS) (NYSE: WDS):
2026 full-year guidance Prior Current ----------------------------------------- --------- ------------- --------- Total production volumes(1) MMboe 172-186 No change ----------------------------------------- --------- ------------- --------- Gas hub exposure(2) % 30 No change ----------------------------------------- --------- ------------- --------- Capital expenditure(3456) $ 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 $ million 4,200 - 4,700 No change depreciation and amortisation ----------------------------------------- --------- ------------- ---------
Woodside CEO Liz Westcott said the company maintained safe and reliable operations across its global portfolio during the first quarter, while continuing to execute major projects to budget and schedule.
"Production for the period was 45.2 million barrels of oil equivalent, underpinned by exceptional reliability of our world-class assets, including 99.9% at Sangomar and 99.0% at Shenzi. In Western Australia, Pluto LNG achieved 100% reliability for the third consecutive quarter, while the North West Shelf Project delivered 99.7%.
"Output from our Western Australian assets was impacted late in the quarter by Severe Tropical Cyclone Narelle. The team's cyclone response ensured we maintained the safety of our people, assets and the environment throughout the shutdown and restoration of operations.
"We have seen modest increases to our portfolio average realised pricing in the quarter, driven by elevated spot prices. Further benefits of currently higher spot prices will be realised in subsequent quarters for LNG due to lagged contract pricing.
"We continued disciplined delivery of major cash-generative growth projects. Our Scarborough Energy Project is 96% complete and on target for first LNG cargo in the fourth quarter of 2026.
"During the period, we also progressed preparations for the Pluto turnaround scheduled for May, supporting long-term asset performance, and advancing readiness for Scarborough start-up.
"We reached key milestones during the quarter at Beaumont New Ammonia, achieving first ammonia cargo in February followed by the successful transition to full operational control of the facility in March.
"We commenced the drilling campaign at Trion, and completed the lift and installation of two topside modules onto the FPU. The project is 56% complete and targeting first oil in 2028.
"Construction at the Louisiana LNG project is progressing well, with structural steel erection, pipe installation, LNG tank construction and marine works underway. Louisiana LNG Train 1 is 31% complete.
"The drilling and completion of the Julimar Development Phase 3 wells was delivered, marking another milestone ahead of the asset swap with Chevron in H2 2026.
"At the time of my appointment in March, I said my focus would be on operational excellence, disciplined execution and sustainable value creation for Woodside shareholders. Cost discipline is essential to sustainable shareholder value creation and we are commencing a structured review of our business to streamline decision making, reduce complexity and improve accountability. We expect this will deliver benefits through improved organisational effectiveness and capital management without compromising safety, execution or operational reliability.
Comparative performance at a glance
Q1 Q4 Change Q1 Change YTD YTD Change
2026 2025 % 2025 % 2026 2025 %
---------------- ---------- ----- ----- ------ ----- ------ ----- ----- ------
Operating
revenue $ million 3,261 3,035 7% 3,315 (2%) 3,261 3,315 (2%)
---------------- ---------- ----- ----- ------ ----- ------ ----- ----- ------
Production
volumes(7) MMboe 45.2 48.9 (8%) 49.1 (8%) 45.2 49.1 (8%)
Gas MMscf/d 1,578 1,709 (8%) 1,841 (14%) 1,578 1,841 (14%)
Liquids Mbbl/d 221 232 (5%) 223 (1%) 221 223 (1%)
Ammonia kT/d 1 -- --% -- --% 1 -- --%
Total Mboe/d 502 531 (5%) 546 (8%) 502 546 (8%)
---------------- ---------- ----- ----- ------ ----- ------ ----- ----- ------
Sales volumes(8) MMboe 51.7 52.4 (1%) 50.3 3% 51.7 50.3 3%
Gas MMscf/d 2,016 1,924 5% 1,968 2% 2,016 1,968 2%
Liquids Mbbl/d 218 232 (6%) 213 2% 218 213 2%
Ammonia kT/d 1 -- --% -- --% 1 -- --%
Total Mboe/d 575 569 1% 559 3% 575 559 3%
---------------- ---------- ----- ----- ------ ----- ------ ----- ----- ------
Average realised
price(7) $/boe 63 57 11% 64 (2%) 62 64 (3%)
---------------- ---------- ----- ----- ------ ----- ------ ----- ----- ------
Capital
expenditure and
acquisitions $ million 1,323 822 61% 1,806 (27%) 1,323 1,806 (27%)
Capital
expenditure $ million 853 822 4% 1,806 (53%) 853 1,806 (53%)
Acquisitions $ million 470 -- -- -- --% 470 -- --%
Operations
Pluto LNG
-- Achieved third consecutive quarterly LNG reliability of 100%.
-- Safely restarted offshore facilities following Severe Tropical Cyclone
Mitchell.
-- Continued preparation for the maintenance turnaround scheduled for May
2026.
-- Completed drilling of the XNA-03 infill well which is targeting
start-up in H2 2026.
North West Shelf (NWS) Project
-- Achieved quarterly LNG reliability of 99.7%.
-- Safely restarted onshore and offshore facilities following Severe
Tropical Cyclone Mitchell and Severe Tropical Cyclone Narelle.
-- Processed higher volumes of Waitsia gas, driven by the continued
ramp--up of Waitsia Stage 2.
-- Advanced preparation for the scheduled one-train LNG maintenance
campaign planned for September 2026.
Wheatstone and Julimar-Brunello
-- Drilling and completion of the Julimar Development Phase 3 wells was
achieved. Start-up is targeting H2 2026.
-- LNG production at Wheatstone was impacted following an unplanned outage
caused by Severe Tropical Cyclone Narelle. Production is partially
restored, with return to normal operation expected by the end of April.
-- Decommissioning of five Julimar Brunello exploration wells is planned
for H2 2026, as a condition precedent for the asset swap with Chevron.
-- Completion of the asset swap with Chevron is targeted for H2 2026.9
Bass Strait
-- Completion of the transfer of operatorship of the Bass Strait assets
from ExxonMobil Australia to Woodside is targeting H2 2026.10
-- Delivered reliability of 89.4% during the quarter, and completed
planned shutdowns of the Snapper and West Tuna platforms ahead of
schedule.
-- Completed drilling two of five wells for the Turrum Phase 3 project,
with drilling targeting completion in H2 2026.
Other Australia
-- The Okha FPSO disconnected in late March 2026 ahead of scheduled
shipyard activity in Q2 2026.
-- The Pyrenees FPSO is scheduled to undertake shipyard activity in Q4
2026.
Sangomar
-- Achieved an average daily production rate of 99 Mbbl/d (100% basis, 80
Mbbl/d Woodside share) with reliability of 99.9%.
-- The Sangomar FPSO continues to demonstrate high reliability and the
overall Sangomar reservoir continues to perform better than expected.
-- Optimisation of wells online and line-up of flowlines and system
hydraulics have enabled maintained strong production through the quarter,
however we expect to see oil rates decline over the remainder of 2026.
United States of America
-- Shenzi completed field production optimisation initiatives including
flowline pressure reduction for sustained production rate increase and
achieved reliability of 99.0%.
-- Commenced water injection from a new well at Atlantis.
-- Successfully commenced production from the third and final Argos
Southwest Extension well, completing the three--well subsea tieback that
began in August 2025. The project is expected to contribute approximately
20 Mbbl/d of gross (100% basis, 5 Mbbl/d Woodside share) peak annualised
average oil production.
Beaumont New Ammonia
-- Assumed operational control of the Beaumont New Ammonia facility in
March 2026 following completion of performance testing and handover from
OCI Global and final payment of $470 million.
-- Achieved first ammonia cargo in February 2026, with 2026 sales
comprising a combination of spot and term cargoes supplied to domestic US
barges and international seaborne vessels.
-- Due to delays at third-party industrial gas suppliers, we are targeting
production of lower-carbon ammonia in 2027.
Marketing
-- There have been no disruptions to Woodside's trading activities as a
result of the conflict in the Middle East, with shipping operations
continuing as planned.
-- Revenue and trading:
-- Continued strong LNG demand for spot cargoes from the Woodside
portfolio at market prices.
-- LNG realised prices broadly flat compared to the prior quarter
due to price lags.
-- Approximately 51% of LNG sold was linked to gas hub indices in
the quarter.
-- Interruptions have increased the demand for crude products
resulting in higher spot market prices.
-- Shipping:
-- Woodside has a strategy of securing term shipping for annual
average delivery commitments and therefore has limited exposure to
volatile spot LNG carrier rates.
-- Woodside does not currently have any controlled shipping that
traverses Iranian waters or the Straits of Hormuz. Woodside trade
routes are not subject to increased security risk.
-- Executed incremental pipeline gas sales of:
-- Approximately 1 PJ to be delivered to the Western Australian
market in 2026.
-- 8.1 PJ to be delivered to the East Coast market across 2026,
2027 and 2028.
-- Woodside continues to engage with the Western Australian market on
additional spot supply in 2026 and requirements for 2027 and onwards.
Projects
Scarborough Energy Project
-- The Scarborough and Pluto Train 2 projects remain on budget and were
96% complete at the end of the quarter (excluding Pluto Train 1
modifications).
-- The FPU was moored at the Scarborough field and hook-up of the
umbilical and all subsea risers was successfully completed. Topsides
commissioning activities are in progress.
-- Subsequent to the period, the Scarborough FPU was registered as a
security regulated offshore facility by the Department of Home Affairs.
-- Construction and commissioning activities at the Pluto Train 2 site
continued, first ignition of the additional gas turbine generator was
achieved and preparation is underway for the first run of the
liquefaction compressors.
-- The first two of three modules built for the Pluto Train 1
modifications project departed the fabrication yard in Thailand and,
subsequent to the quarter, arrived at the Pluto site.
-- Civil, structural, and piping works advanced at the Pluto site, with a
focus on preparing for activities to be completed during the Pluto LNG
Train 1 major turnaround scheduled for May 2026.
-- First LNG cargo is on track for Q4 2026.
Trion
-- The Trion Project remains on budget and was 56% complete at the end of
the quarter.
-- Drilling of 24 subsea wells commenced in March 2026.
-- Subsea equipment is on track for Q3 2026 installation.
-- FPU construction reached key milestones, with hull structural
fabrication completed and two 6,000--metric--ton topside modules
successfully lifted and installed.
-- Floating storage and offloading structural block fabrication continued,
with the disconnectable turret mooring buoy largely complete and mating
tests finished.
-- The Middle East conflict is currently not having any material impact on
cost or schedule for Trion.
-- The Trion Project is targeting first oil in 2028.
Louisiana LNG
-- The foundation phase of Louisiana LNG, comprising three trains, reached
24% complete at the end of the quarter and remains on budget.
-- Key milestones achieved during the period included progression of the
LNG tanks and the commencement of dredging activities.
-- Train 1 was 31% complete at the end of the quarter. During the period,
structural steel erection progressed and the first piping was installed
in the Train 1 rack.
-- Trains 2 and 3 were 22% and 14% complete respectively at the end of the
quarter, with piling installation completed for Train 2 and commenced for
Train 3.
-- Transition of Driftwood Pipeline LLC operatorship to Williams
completed.
-- Bechtel is sourcing Louisiana LNG structural steel from the United Arab
Emirates. Fabrication at Bechtel's facility has not been impacted and
sufficient steel for 2026 work programs has been delivered to site.
Mitigation measures are being proactively assessed to ensure ongoing
supply of steel.
-- Louisiana LNG continues to attract strong interest from high-quality
counterparties, supporting Woodside's sell-down process.
-- Progressed potential future growth optionality for the project.
-- The project is targeting first LNG cargo 2029.
Hydrogen Refueller @H2Perth
-- Commissioning activities continued ahead of targeted ready for start-up
in Q2 2026.
-- The project is targeting first hydrogen production in H2 2026.11
Decommissioning
-- Progressed offshore decommissioning execution activities across the
portfolio, including removal of more than 18 km of flexible flowlines and
umbilicals at Stybarrow and 8 km of flexible flowlines from Griffin
fields.
-- Continued technical studies across the Stybarrow, Griffin and Minerva
decommissioning projects to support execution planning, consistent with
regulatory requirements.
-- At Bass Strait (Gippsland Basin Joint Venture), well plug and
abandonment activities were progressed with platform rig operations on
West Kingfish and Cobia platforms.
-- Preparation activities for the Bass Strait Offshore Platform Removal
Campaign 1 also progressed, including completion of preparation
activities on Bream B Platform, and commencement of mobilisation for
onshore reception centre upgrades.
Development and exploration
Browse
-- Continued engagement with regulators to progress environmental
approvals.
-- Continued technical work to optimise the upstream concept, with
contractors engaged to progress pre-Front-End Engineering and Design
$(FEED)$ engineering scopes for the FPSO facilities.
-- Issued invitations to tender for the design and construction of the
Browse FPSO facilities that will provide market pricing and schedule
assumptions to inform a FEED entry decision.
-- Progressed the gas processing agreement which will establish the
commercial framework and terms for processing Browse gas at the North
West Shelf Project's Karratha Gas Plant and support FEED entry.
Sunrise
-- Progressed technical and commercial activities under the Timor--Leste
Cooperation Agreement.
-- Ongoing engagement by the Sunrise Joint Venture with the Timor--Leste
and Australian Governments to advance the fiscal and regulatory
frameworks supporting the potential development of Sunrise.
Calypso
-- The Calypso Joint Venture progressed the scoping of additional
engineering studies.
Exploration
-- Woodside participated in the non-operated Bandit-1 well in Green Canyon
Block 680 in the Gulf of America, which encountered high-quality
oil-bearing Miocene sands. The co-owners are currently evaluating results
to determine next steps.12
-- Woodside was awarded eight leases in the Gulf of America following
final payment and regulatory approval as the successful bidder from the
Big Beautiful Gulf 1 Lease Sale held in 2025.
-- Woodside was the successful bidder on two blocks in Big Beautiful Gulf
2 Lease Sale in the Gulf of America, with the lease issuance pending
final payment and regulatory approval.
-- Continued to evaluate opportunities consistent with Woodside's
disciplined exploration strategy.
Corporate activities
CEO appointment
-- The Board appointed Liz Westcott as Woodside's CEO and Managing
Director, effective 18 March 2026.
Annual General Meeting
-- Woodside's Annual General Meeting $(AGM)$ was held on 23 April 2026. -- All items put to the AGM were carried, and the AGM voting results were published following the meeting.
Climate and sustainability
-- Published AASB S2 climate-related disclosures in the 2025 Annual
Report.
-- "Woodside Sustainability Briefing 2026" held on 16 March, highlighting
2025 sustainability performance.
-- Subsequent to the period, the 2025 Social Contribution Report was
released, outlining our focus on the generation of better social and
economic outcomes for our host communities.
Hedging
-- As at 31 March 2026, 30 MMboe of 2026 oil production was hedged at an
average price of $74.23 per barrel and 10 MMboe of 2027 production at
$76.76 per barrel.
-- Continued hedging program for Corpus Christi LNG volumes involving
Henry Hub and Title Transfer Facility (TTF) commodity swaps.
Approximately 95% of 2026, 86% of 2027, and 7% of 2028 volumes have been
hedged.
-- The realised value of all hedged positions for the period ended 31
March 2026 is an estimated pre-tax profit of $32 million, with a $24
million profit related to Corpus Christi hedges and a $9 million profit
related to oil price hedges, offset by a $1 million loss related to other
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 2026 financial statements.
Embedded commodity derivative
-- In 2023, Woodside entered into 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 the quarter ended 31 March 2026, an unrealised pre-tax loss of
approximately $41 million is expected to be recognised through other
expense.
Funding and liquidity
-- As at 31 March 2026, Woodside had liquidity of approximately $8,300
million, after paying a fully franked dividend in March, and net debt
(including lease liabilities) of approximately $9,300 million.
Upcoming events 2026-2027
July 29 Second Quarter Report
--------- -----------------------
August 25 Half-Year 2026 Results
--------- -----------------------
October 21 Third Quarter Report
--------- -----------------------
January 28 Fourth Quarter Report
--------- -----------------------
February 23 2026 Annual Report
--------- -----------------------
Production volumes
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
--------------------------- -------- ----- ----- ----- ----- -----
Gas MMscf/d 1,578 1,709 1,841 1,578 1,841
Liquids Mbbl/d 221 232 223 221 223
Ammonia kT/d 1 -- -- 1 --
--------------------------- -------- ----- ----- ----- ----- -----
Total production volumes Mboe/d 502 531 546 502 546
--------------------------- -------- ----- ----- ----- ----- -----
Production (reserves)
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
------------------------- ------- ------ ------ ------ ------ ------
AUSTRALIA
LNG
North West Shelf Mboe 5,678 6,091 6,395 5,678 6,395
Pluto(13) Mboe 10,991 11,403 10,226 10,991 10,226
Wheatstone Mboe 2,286 2,390 2,422 2,286 2,422
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 18,955 19,884 19,043 18,955 19,043
------------------------- ------- ------ ------ ------ ------ ------
Pipeline gas
Bass Strait Mboe 2,756 3,431 3,192 2,756 3,192
Other(13,14) Mboe 2,508 3,598 3,740 2,508 3,740
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 5,264 7,029 6,932 5,264 6,932
------------------------- ------- ------ ------ ------ ------ ------
Crude oil and condensate
North West Shelf Mbbl 953 1,083 1,106 953 1,106
Pluto(13) Mbbl 845 930 847 845 847
Wheatstone Mbbl 427 436 441 427 441
Bass Strait Mbbl 342 367 402 342 402
Macedon & Pyrenees Mbbl 361 430 369 361 369
Ngujima-Yin Mbbl 653 973 725 653 725
Okha Mbbl 311 452 312 311 312
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 3,892 4,671 4,202 3,892 4,202
------------------------- ------- ------ ------ ------ ------ ------
NGL
North West Shelf Mbbl 181 247 230 181 230
Pluto(13) Mbbl 39 48 47 39 47
Bass Strait Mbbl 630 631 668 630 668
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 850 926 945 850 945
------------------------- ------- ------ ------ ------ ------ ------
Total Australia Mboe 28,961 32,510 31,122 28,961 31,122
------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 322 353 346 322 346
--------------------------------- ------ ------ ------ ------ ------
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
----------------------------- ------- ------ ------ ------ ------ ------
INTERNATIONAL
Pipeline gas
USA Mboe 446 408 378 446 378
Trinidad & Tobago Mboe - - 2,416 - 2,416
Other(15) Mboe 9 - 23 9 23
----------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 455 408 2,817 455 2,817
----------------------------- ------- ------ ------ ------ ------ ------
Crude oil and condensate
Atlantis Mbbl 2,721 2,761 2,472 2,721 2,472
Mad Dog Mbbl 2,758 2,797 2,577 2,758 2,577
Shenzi Mbbl 1,896 1,958 2,322 1,896 2,322
Trinidad & Tobago Mbbl - - 99 - 99
Sangomar Mbbl 7,152 7,781 7,010 7,152 7,010
Other(15) Mbbl 54 34 - 54 -
----------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 14,581 15,331 14,480 14,581 14,480
----------------------------- ------- ------ ------ ------ ------ ------
NGL
USA Mbbl 513 363 398 513 398
Other(15) Mbbl 5 - 12 5 12
----------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 518 363 410 518 410
----------------------------- ------- ------ ------ ------ ------ ------
Total International Mboe 15,554 16,102 17,707 15,554 17,707
----------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 173 175 197 173 197
------------------------------------- ------ ------ ------ ------ ------
Total production (reserves)
volumes Mboe 44,515 48,612 48,829 44,515 48,829
----------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 495 528 543 495 543
------------------------------------- ------ ------ ------ ------ ------
Production (processing)
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
----------------------------- ------- ------ ------ ------ ------ ------
AUSTRALIA
Pluto-KGP Interconnector(16)
LNG Mboe 242 180 204 242 204
Pipeline gas Mboe - 75 67 - 67
Crude oil and condensate Mbbl 9 9 10 9 10
NGL Mbbl 4 5 5 4 5
----------------------------- ------- ------ ------ ------ ------ ------
Total Australia Mboe 255 269 286 255 286
----------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 3 3 3 3 3
------------------------------------- ------ ------ ------ ------ ------
INTERNATIONAL
Beaumont New Ammonia(17) Mboe 417 10 - 417 -
----------------------------- ------- ------ ------ ------ ------ ------
Total International Mboe 417 10 - 417 -
----------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 5 - - 5 -
------------------------------------- ------ ------ ------ ------ ------
Total production (processing)
volumes Mboe 672 279 286 672 286
----------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 7 3 3 7 3
------------------------------------- ------ ------ ------ ------ ------
Total production volumes Mboe 45,187 48,891 49,115 45,187 49,115
----------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 502 531 546 502 546
------------------------------------- ------ ------ ------ ------ ------
Sales volumes
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
---------------------- -------- ----- ----- ----- ----- -----
Gas MMscf/d 2,016 1,924 1,968 2,016 1,968
Liquids Mbbl/d 218 232 213 218 213
Ammonia kT/d 1 -- -- 1 --
---------------------- -------- ----- ----- ----- ----- -----
Total sales volumes Mboe/d 575 569 559 575 559
---------------------- -------- ----- ----- ----- ----- -----
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
------------------------- ------- ------ ------ ------ ------ ------
AUSTRALIA
LNG
North West Shelf Mboe 7,464 5,797 6,887 7,464 6,887
Pluto Mboe 11,905 11,703 9,676 11,905 9,676
Wheatstone Mboe 2,616 2,974 2,217 2,616 2,217
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 21,985 20,474 18,780 21,985 18,780
------------------------- ------- ------ ------ ------ ------ ------
Pipeline gas
Bass Strait Mboe 2,566 3,456 3,299 2,566 3,299
Other(18) Mboe 2,498 3,440 3,584 2,498 3,584
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 5,064 6,896 6,883 5,064 6,883
------------------------- ------- ------ ------ ------ ------ ------
Crude oil and condensate
North West Shelf Mbbl 682 1,225 1,229 682 1,229
Pluto Mbbl 1,192 661 705 1,192 705
Wheatstone Mbbl 268 648 334 268 334
Bass Strait Mbbl 528 - 534 528 534
Ngujima-Yin Mbbl 669 747 663 669 663
Okha Mbbl 251 654 - 251 -
Macedon & Pyrenees Mbbl 1 438 499 1 499
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 3,591 4,373 3,964 3,591 3,964
------------------------- ------- ------ ------ ------ ------ ------
NGL
North West Shelf Mbbl - 223 477 - 477
Pluto Mbbl - 66 110 - 110
Bass Strait Mbbl 866 598 226 866 226
------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 866 887 813 866 813
------------------------- ------- ------ ------ ------ ------ ------
Total Australia Mboe 31,506 32,630 30,440 31,506 30,440
------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 350 355 338 350 338
--------------------------------- ------ ------ ------ ------ ------
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
---------------------------- ------- ------ ------ ------ ------ ------
INTERNATIONAL
Pipeline gas
USA(19) Mboe 386 331 387 386 387
Trinidad & Tobago Mboe - - 2,274 - 2,274
Other(20) Mboe 3 5 4 3 4
---------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 389 336 2,665 389 2,665
---------------------------- ------- ------ ------ ------ ------ ------
Crude oil and condensate
Atlantis Mbbl 2,728 2,729 2,494 2,728 2,494
Mad Dog Mbbl 2,733 2,710 2,620 2,733 2,620
Shenzi Mbbl 1,894 1,931 2,202 1,894 2,202
Trinidad & Tobago Mbbl - - 43 - 43
Sangomar Mbbl 6,822 7,603 6,521 6,822 6,521
Other(20) Mbbl 89 41 57 89 57
---------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 14,266 15,014 13,937 14,266 13,937
---------------------------- ------- ------ ------ ------ ------ ------
NGL
USA Mbbl 522 350 371 522 371
Other(20) Mbbl 2 3 2 2 2
---------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 524 353 373 524 373
---------------------------- ------- ------ ------ ------ ------ ------
Ammonia
Beaumont New Ammonia(21) Mboe 249 - - 249 -
---------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 249 - - 249 -
---------------------------- ------- ------ ------ ------ ------ ------
Total International Mboe 15,428 15,703 16,975 15,428 16,975
---------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 171 171 189 171 189
------------------------------------ ------ ------ ------ ------ ------
MARKETING(22)
LNG Mboe 4,400 3,341 2,750 4,400 2,750
Liquids Mboe 384 695 104 384 104
---------------------------- ------- ------ ------ ------ ------ ------
Total Mboe 4,784 4,036 2,854 4,784 2,854
---------------------------- ------- ------ ------ ------ ------ ------
Total Marketing Mboe 4,784 4,036 2,854 4,784 2,854
---------------------------- ------- ------ ------ ------ ------ ------
Total sales volumes Mboe 51,718 52,369 50,269 51,718 50,269
---------------------------- ------- ------ ------ ------ ------ ------
Mboe/d 575 569 559 575 559
------------------------------------ ------ ------ ------ ------ ------
Operating revenue (US$ million)
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
-------------------------------- ----- ----- ----- ----- -----
AUSTRALIA
North West Shelf 448 381 535 448 535
Pluto 766 800 712 766 712
Wheatstone 180 230 199 180 199
Bass Strait 232 212 228 232 228
Macedon 56 54 52 56 52
Ngujima-Yin 48 48 57 48 57
Okha 25 44 - 25 -
Pyrenees - 29 44 - 44
-------------------------------- ----- ----- ----- ----- -----
Revenue from sale of products 1,755 1,798 1,827 1,755 1,827
Intersegment revenue (50) (44) (2) (50) (2)
Processing and services revenue 53 29 74 53 74
-------------------------------- ----- ----- ----- ----- -----
Total Australia 1,758 1,783 1,899 1,758 1,899
-------------------------------- ----- ----- ----- ----- -----
INTERNATIONAL
Atlantis 199 169 191 199 191
Mad Dog 190 159 190 190 190
Shenzi 138 117 167 138 167
Trinidad & Tobago(23) - - 66 - 66
Sangomar 524 479 481 524 481
Other(24) 42 2 3 42 3
-------------------------------- ----- ----- ----- ----- -----
Revenue from sale of products 1,093 926 1,098 1,093 1,098
-------------------------------- ----- ----- ----- ----- -----
Total International 1,093 926 1,098 1,093 1,098
-------------------------------- ----- ----- ----- ----- -----
MARKETING
Revenue from sale of products 360 273 312 360 312
Intersegment revenue 50 44 2 50 2
Shipping and other revenue - 9 4 - 4
-------------------------------- ----- ----- ----- ----- -----
Total Marketing(25) 410 326 318 410 318
-------------------------------- ----- ----- ----- ----- -----
Operating revenue(26) 3,261 3,035 3,315 3,261 3,315
-------------------------------- ----- ----- ----- ----- -----
Realised prices
Q1 Q4 Q1 Q1 Q4 Q1
Units 2026 2025 2025 Units 2026 2025 2025
--------------------- -------- ---- ---- ----- ----- ----- ----- -----
LNG produced $/MMBtu 9.0 9.4 10.6 $/boe 57 59 67
LNG traded(27) $/MMBtu 10.0 9.9 13.7 $/boe 65 62 86
Pipeline gas $/boe 44 39 36
Oil and condensate $/bbl 77 62 74 $/boe 77 62 74
NGL $/bbl 38 37 47 $/boe 38 37 47
Liquids traded(27) $/bbl 85 54 70 $/boe 85 54 70
Average realised price for
pipeline gas:
Western Australia A$/GJ 7.0 6.9 6.9
East Coast
Australia A$/GJ 14.1 12.6 14.0
International(28) $/Mcf 5.7 4.3 4.8
Average realised
price $/boe 63 57 64
Dated Brent $/bbl 81 64 76
JCC (lagged three
months) $/bbl 72 72 78
WTI $/bbl 72 59 71
JKM $/MMBtu 10.4 11.2 14.7
TTF $/MMBtu 10.8 10.8 14.6
Average realised price increased 11% from the prior quarter primarily due to:
-- LNG traded sales from the Woodside portfolio at higher spot market
prices; and
-- Oil and condensate and liquids traded sales at higher Dated Brent and
West Texas Intermediate $(WTI)$ market prices. The oil and condensate
quarterly realised price includes a revenue adjustment of $75 million
which will be reported within "other income" in the Financial Statements.
This adjustment represents the increase in market prices between the date
revenue is recognised, based on provisional pricing and the expected
final price paid by the customer.
Capital expenditure (US$ million)
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
------------------------------------------- ----- ----- ----- ----- -----
Evaluation capitalised(29) 9 7 12 9 12
Property plant & equipment 1,686 1,443 1,790 1,686 1,790
Cash contributions from participants (847) (600) - (847) -
Other(30) 5 (28) 4 5 4
------------------------------------------- ----- ----- ----- ----- -----
Capital expenditure 853 822 1,806 853 1,806
------------------------------------------- ----- ----- ----- ----- -----
Acquisitions 470 - - 470 -
------------------------------------------- ----- ----- ----- ----- -----
Total capital expenditure and acquisitions 1,323 822 1,806 1,323 1,806
------------------------------------------- ----- ----- ----- ----- -----
Q1 Q4 Q1 YTD YTD
2026 2025 2025 2026 2025
---------------------------------------- ----- ----- ----- ----- -----
Scarborough 275 389 322 275 322
Trion 171 186 315 171 315
Louisiana LNG capital expenditure 872 505 901 872 901
Cash contributions from participants (847) (600) - (847) -
Louisiana LNG other(30) 5 (37) - 5 -
Louisiana LNG 30 (132) 901 30 901
Other 377 379 268 377 268
---------------------------------------- ----- ----- ----- ----- -----
Capital expenditure 853 822 1,806 853 1,806
---------------------------------------- ----- ----- ----- ----- -----
Other expenditure (US$ million)
Q1 Q4 Q1 YTD YTD
Exploration and evaluation expenditure 2026 2025 2025 2026 2025
---------------------------------------- ----- ----- ----- ----- -----
Exploration capitalised(29,31) 40 18 5 40 5
Exploration and evaluation expensed(32) 50 56 35 50 35
Permit amortisation 2 - 3 2 3
---------------------------------------- ----- ----- ----- ----- -----
Total 92 74 43 92 43
---------------------------------------- ----- ----- ----- ----- -----
Q1 Q4 Q1 YTD YTD
Trading costs 2026 2025 2025 2026 2025
---------------------------------------- ----- ----- ----- ----- -----
Australia 49 58 39 49 39
Marketing 338 232 193 338 193
---------------------------------------- ----- ----- ----- ----- -----
Total 387 290 232 387 232
---------------------------------------- ----- ----- ----- ----- -----
Q1 Q4 Q1 YTD YTD
Abandonment expenditure 2026 2025 2025 2026 2025
---------------------------------------- ----- ----- ----- ----- -----
Total 116 165 257 116 257
---------------------------------------- ----- ----- ----- ----- -----
Exploration or appraisal wells drilled
Actual
Water well
Permit depth depth
Region area Well Target Interest (%) Spud date (m) (m)(33) Remarks
------- ------- --------- ------- ------------- ---------- ----- ------- -----------
Encountered
2 oil in
United 17.5% September Miocene
States GC 680 Bandit-1 Oil Non-operator 2025 1,555 11,139 interval
------- ------- --------- ------- ------------- ---------- ----- ------- -----------
Permits and licences
Key changes to permit and licence holdings during the quarter ended 31 March
2026 are noted below.
Permits or Change in Current
Region licence areas interest (%) interest (%) Remarks
-------------- ---------------- ------------- ------------- --------------
Australia WA-28-P (100.0%) -- Permit expired
-------------- ---------------- ------------- ------------- --------------
WR 443, WR 444,
United States WR 488 80% 80% Awarded
-------------- ---------------- ------------- ------------- --------------
KC 259, KC 301, KC 343, KC 431,
WR 577 100% 100% Awarded
------------------------------- ------------- ------------- --------------
Production rates
Average daily production rates (100% project) for the quarter ended 31 March
2026:
Production rate
(100% project,
Woodside share(34) Mboe/d) Remarks
Mar Dec
2026 2025
------------------- ------------------ -------- ------- ------------------
AUSTRALIA
NWS Project
Production was
lower due to
impact from
LNG 30.04% 210 220 adverse weather.
Crude oil and
condensate 30.07% 35 39
NGL 30.09% 7 9
Pluto LNG
Production was
lower due to
impact from
LNG 90.00% 109 118 adverse weather.
Crude oil and
condensate 90.00% 9 10
Pluto-KGP
Interconnector
LNG production was
higher due to
increased feed gas
to Karratha Gas
LNG 100.00% 27 20 Plant.
Crude oil and
condensate 100.00% 1 1
NGL 100.00% -- 1
Wheatstone(35)
Production was
lower due to
impact from
LNG 11.78% 211 235 adverse weather.
Crude oil and
condensate 16.21% 29 31
Bass Strait
Pipeline gas
production was
lower due to
reduced seasonal
demand and planned
offshore
maintenance
Pipeline gas 46.95% 65 73 activities.
Crude oil and
condensate 42.16% 9 9
NGL 44.70% 16 15
Australia Oil
Production was
lower due to
impact from
adverse weather
and planned
shipyard
maintenance for
Ngujima-Yin 60.00% 12 18 Okha.
Okha 50.00% 7 10
Pyrenees 63.40% 6 7
Other
Pipeline gas(36) 28 40 Production was
lower due to
reduced
nominations.
Production rate
(100% project,
Woodside share(37) Mboe/d) Remarks
Mar Dec
2026 2025
------------------- ------------------ -------- ------- ------------------
INTERNATIONAL
Atlantis
Crude oil and
condensate 38.50% 79 78
NGL 38.50% 7 4
Pipeline gas 38.50% 10 8
Mad Dog
Crude oil and
condensate 20.86% 147 146
NGL 20.86% 7 5
Pipeline gas 20.86% 3 3
Shenzi
Crude oil and
condensate 64.60% 33 33
NGL 64.65% 3 2
Pipeline gas 64.57% 1 1
Sangomar
Crude oil 79.79%(38) 100 99
Beaumont New
Ammonia
Plant
commissioning and
Ammonia(39) 100.00% 5 -- start-up.
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 targets and Scope 3 investment and emissions abatement targets (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 guidance, forecasts, guarantees or predictions of future events or performance, but are in the nature of future expectations that are based on management's current expectations. 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 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.
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. 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 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
All figures are Woodside share for the quarter ending 31 March 2026, 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).
Glossary, units of measure and conversion factors Refer to the Glossary in the Annual Report 2025 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. ------------------------------------------------------------------------------ Term Definition ------------- --------------------------------------------------------------- bbl barrel ------------- --------------------------------------------------------------- bcf billion cubic feet of gas ------------- --------------------------------------------------------------- boe barrel of oil equivalent ------------- --------------------------------------------------------------- GJ gigajoule ------------- --------------------------------------------------------------- kT thousand metric tonnes ------------- --------------------------------------------------------------- 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 ------------- --------------------------------------------------------------- Glossary
Please refer to the Glossary in the Annual Report 2025 for definitions, including carbon related definitions.
(1) Total production volumes includes 2-3 MMboe from Beaumont New Ammonia.
(2) Gas hub indices include Japan Korea Marker (JKM), Title Transfer Facility (TTF) and National Balancing Point $(NBP)$. It excludes Henry Hub. Presented on a three-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) Louisiana LNG (90% Louisiana LNG LLC, 60% Louisiana LNG Infrastructure LLC and 20% Driftwood Pipeline LLC) capital expenditure adjusted for the cash contributions from Stonepeak and Williams.
(4) Scarborough at 74.9% participating interest, Pluto Train 2 at 51% participating interest.
(5) Trion at 60% participating interest.
(6) Completion of the asset swap with Chevron assumed in H2 2026. Woodside's equity interests at current participating interests prior to the completion for NWS Project, NWS Oil Project, Wheatstone, Julimar-Brunello and Angel CCS assets.
(7) Percent change in total production may differ from percent change in daily production due to the number of days in each quarter.
(8) Restated additional volumes of 0.09 MMboe in Q1 2025 to reflect a revised MMBtu to boe conversion factor, impacting realised price by -$1/boe in Q1 2025.
(9) Completion of the transaction is subject to conditions precedent. See "Woodside simplifies portfolio and unlocks long-term value" announced on 19 December 2024.
(10) Completion of the transaction is subject to conditions precedent. See "Woodside strengthens its Australian Operations" announced on 29 July 2025.
(11) The project has received funding from the Hydrogen Fuelled Transport Project Funding Process as part of the Western Australian Government's Renewable Hydrogen Strategy.
(12) See "Bandit-1 discovery off Louisiana" announced on 10 April 2026.
(13) 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.
(14) Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.
(15) Overriding royalty interests held in the USA for several producing wells.
(16) Feed gas volumes purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.
(17) Beaumont New Ammonia production volume is 113.3 kT in Q1 2026 and YTD 2026.
(18) Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.
(19) Restated additional volumes of 0.09 MMboe in Q1 2025 to reflect a revised MMBtu to boe conversion factor.
(20) Overriding royalty interests held in the USA for several producing wells.
(21) Beaumont New Ammonia sales volumes are 67.6 kT in Q1 2026 and YTD 2026.
(22) Purchased volumes sourced from third parties.
(23) Includes the impact of periodic adjustments related to the production sharing contract $(PSC)$.
(24) Includes revenue from Beaumont New Ammonia and overriding royalty interests held in the USA for several producing wells.
(25) 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.
(26) Operating revenue excludes all hedging impacts.
(27) Excludes any additional benefit attributed to produced volumes through third-party trading activities.
(28) Sales volumes have been restated to reflect volumes sold in MMBtu at a revised boe conversion factor impacting realised price by -$0.2/Mcf for International pipeline gas and -$1/boe for Group in Q1 2025.
(29) 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.
(30) Other primarily incorporates Louisiana LNG net payments to/from Williams for Driftwood Pipeline LLC associated with 2025 capital reimbursement included in sell-down proceeds and ongoing cash call payments.
(31) 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.
(32) Includes seismic and general permit activities and other exploration costs.
(33) Well depths are referenced to the rig rotary table.
(34) Woodside share reflects the net realised interest for the period.
(35) 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.
(36) Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.
(37) Woodside share reflects the net realised interest for the period.
(38) Operations governed by production sharing contracts.
(39) Beaumont New Ammonia production rate is 1 kT/d in Mar 2026.
This announcement was approved and authorised for release by Woodside's Disclosure Committee.
View source version on businesswire.com: https://www.businesswire.com/news/home/20260428301421/en/
CONTACT: INVESTORS
Vanessa Martin
M: +61 477 397 961
E: investor@woodside.com
MEDIA
Christine Abbott
M: +61 484 112 469
E: christine.abbott@woodside.com
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
(END) Dow Jones Newswires
April 28, 2026 20:38 ET (00:38 GMT)
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