Exhibit 99.1

Woodside Energy Group Ltd

ACN 004 898 962

Mia Yellagonga

11 Mount Street

Perth WA 6000

Australia

T +61 8 9348 4000

www.woodside.com

ASX: WDS

NYSE: WDS

LSE: WDS

Announcement

Friday, 21 April 2023

FIRST QUARTER REPORT FOR PERIOD ENDED 31 MARCH 2023

Delivering reliable production

• Delivered quarterly production of 46.8 MMboe (520 Mboe/day), down 9% from Q4 2022 due to planned turnaround and maintenance activities. Full-year production guidance remains unchanged.

• Delivered sales volume of 50.4 MMboe, down 4% from Q4 2022, primarily due to lower production.

• Delivered revenue of $4,330 million, down 16% from Q4 2022, due to lower production and lower realised prices.

• Production, sales volume and revenue increased 122%, 112% and 81% respectively from Q1 2022, driven by the expanded operations portfolio post-merger.

• Achieved high LNG reliability of 99.9% at Pluto LNG and 98.3% at North West Shelf (NWS) Project.

• Achieved a portfolio average realised price of $85 per barrel of oil equivalent.

• Sold 32% of produced LNG at prices linked to gas hub indices.

Executing major projects

• The Scarborough and Pluto Train 2 projects in Western Australia are now 30% complete, with manufacturing of the export trunkline 86% complete and first concrete poured for Pluto Train 2.

• The development drilling program for Sangomar progressed, with ten of 23 wells complete. The Sangomar floating production storage and offloading (FPSO) topsides integration and pre-commissioning works continued in Singapore.

• Subsequent to the period, Mad Dog Phase 2, in the Gulf of Mexico (GoM), successfully achieved first production and will continue to ramp up through 2023.

Investing in growth

• Received competitive tenders for Trion, which are currently being evaluated in support of targeted final investment decision (FID) readiness in 2023.

• Progressed key project activities for H2OK to support targeted FID readiness in 2023.

Page 1 of 15

Woodside CEO Meg O’Neill said Woodside delivered outstanding operational performance in the quarter, particularly at Pluto LNG where reliability averaged 99.9%.

“Our operations teams continued to achieve strong outcomes. Production was 122% higher than the corresponding quarter last year, demonstrating the significant value generated by the merger with BHP’s petroleum business.

“Production and revenue declined from Q4 2022 primarily due to planned turnaround and maintenance activities at Australian assets and lower realised prices.

“We are making good progress on all major growth projects in Australia and globally. The Scarborough and Pluto Train 2 projects are now 30% complete, with construction of key offshore and onshore infrastructure ramping up. First concrete has now been poured on the Pluto Train 2 site. Engagement with stakeholders and regulators on secondary environmental approvals for offshore execution activities continued.

“The Sangomar development drilling program is nearing its half-way point, with ten of 23 wells completed. Installation and testing of the rigid flowlines, which total 101km in length, were successfully and safely completed. This is a key milestone on the path to targeted first oil later this year.

“At the Trion project in the GoM, we have received tenders for key equipment and activities including the floating production unit, long-lead rotating equipment, subsea equipment, drilling rig and installation scopes as we target FID readiness this year.

“Mad Dog Phase 2 in the US GoM achieved a significant milestone with first production in April 2023. Mad Dog is one of several low cost producing assets for Woodside in the region with significant expansion potential and in close proximity to infrastructure and attractive markets.

“Within our new energy business, we continue to progress activities and approvals for our H2OK project in support of achieving FID readiness this year,” she said.

Comparative performance at a glance

		Q1 2023		Q4 2022		Change%			Q1 2022		Change%
Production1	MMboe		46.8		51.6		(9	%)		21.1		122	%
	Mboe/day		520		561					234
Sales	MMboe		50.4		52.2		(4	%)		23.8		112	%
Revenue	$ million		4,330		5,160		(16	%)		2,395		81	%

Operational overview

Production

• Production decreased compared to the previous quarter to 46.8 MMboe, primarily due to:

• planned turnaround on Ngujima-Yin FPSO

• planned onshore and offshore maintenance activities and lower Australian east coast gas market demand on Bass Strait

• Production was more than double the corresponding quarter last year, driven by the expanded operations portfolio post-merger.

• Delivered high reliability at Pluto LNG, achieving 99.9% reliability for the quarter, and maintained strong reliability at NWS Project, achieving 98.3% reliability for the quarter.

Australian LNG

• Commenced front-end engineering design (FEED) and identified long-lead order requirements for the Lambert West development. Lambert West consists of one production well developed via a subsea tie-back to the Angel Platform to support ongoing production from the NWS Project.

¹ Q1 2023 includes 0.31 MMboe, Q4 2022 includes 0.31 MMboe and Q1 2022 includes 0.03 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.

Page 2 of 15

Bass Strait

• Significant planned turnaround and maintenance activities were completed on the onshore and offshore facilities.

• The Gippsland Basin Joint Venture (GBJV) executed an agreement to charter a fourth semi-submersible vessel from the end of 2023 to support decommissioning activities in the Gippsland Basin.

Gulf of Mexico

• The SN102 well was completed and SN101 well completion activities commenced on the Shenzi North project. The project is 67% complete.

Australia Oil

• The Pyrenees Phase 4 infill campaign, comprising a workover well and one infill well, was completed.

• The Enfield plugging and abandonment (P&A) campaign continued with four wells permanently plugged. At the end of the quarter, the plugging of nine of 18 Enfield wells and removal of 13 of 18 xmas trees had been completed.

• The Ngujima-Yin FPSO commenced a planned five-yearly maintenance turnaround in a Singapore drydock and is expected to return to production in Q3 2023.

Project and development activities

Scarborough

• Scarborough upstream pipeline manufacturing is 86% complete. Subsea structure manufacturing and trunkline shore crossing preparations at Pluto commenced. Fabrication of the floating production unit topsides and hull has ramped up.

• Engagement with regulators on secondary environmental approvals for offshore execution activities continued.

• Pluto Train 2 site pre-works progressed with first concrete pour for permanent structures completed and LNG train module construction ramping up.

• Pluto Train 1 modifications scope progressed into pre-execution phase, engineering and long-lead item procurement commenced.

• The project was 30% complete at the end of the period and first LNG cargo is targeted in 2026.

Sangomar Field Development Phase 1

• Installation and testing of the rigid flowlines, totalling 101km in length, were successfully and safely completed.

• The subsea installation campaign progressed, with umbilical installation now 37% complete.

• The development drilling program continued with ten of 23 wells completed.

• FPSO topsides integration and pre-commissioning works continued in Singapore.

• The project was 82% complete at the end of the period and first oil is targeted in late 2023.

Mad Dog Phase 2

• Subsequent to the period, first production was successfully achieved at the Argos platform in the GoM. Production will ramp-up through 2023.

Trion

• Tenders were received and are being evaluated for key scopes including the floating production unit (FPU), long-lead rotating equipment, subsea equipment, drilling rig and installation scopes.

• Woodside is collaborating with PEMEX and the National Hydrocarbons Commission (CNH) on the draft field development plan (FDP), which would be submitted to the regulator following a positive FID.

• Woodside is targeting FID readiness in 2023.

Page 3 of 15

Sunrise

• In February 2023, the Sunrise Joint Venture committed to undertake a concept select program for the development of the Greater Sunrise fields in parallel with the ongoing negotiation of a new production sharing contract and associated agreements with the Timor-Leste and Australian Governments.

New energy

H2OK

• Woodside is progressing negotiations for access to wastewater and the ~200MW of power required.

• Discussions with potential H2OK customers are ongoing.

• The air quality permit approval was received from Oklahoma Department of Environment and Quality.

• Contracting activities for construction tender and other schedule critical packages are progressing.

• H2OK is targeting FID readiness in 2023.

Woodside Solar

• The Woodside Solar development application was submitted to the City of Karratha.

• The Ngarluma and Woodside Power Project Indigenous Land Use Agreement (ILUA) was listed on the Register of ILUAs by the National Native Title Tribunal on 10 March 2023.

• Woodside Solar is targeting FID readiness in 2023.

Corporate activities

Hedging (as at 31 March 2023)

• Woodside has placed oil price hedges for approximately 21.8 MMboe of 2023 production at an average price of $74.5 per barrel of which approximately 5.8 MMboe has been delivered.

• Woodside also has a hedging program for Corpus Christi LNG volumes to protect against downside pricing risk. These hedges are Henry Hub and Title Transfer Facility (TTF) commodity swaps. Approximately 83% of Corpus Christi volumes for the remainder of 2023 and approximately 29% of 2024 volumes have reduced pricing risk as a result of hedging activities.

• The year-to-date pre-tax expense related to hedged positions is approximately $166 million, with $79 million pre-tax expense related to Corpus Christi hedges, $70 million pre-tax expense related to oil price hedges and $17 million pre-tax expense related to other hedge positions. Hedging losses will be included in “other expenses” in the full-year financial statements.

2023 Annual General Meeting

• The 2023 Annual General Meeting (AGM) of Woodside Energy Group Ltd will be held at 10.00am (AWST) on Friday, 28 April 2023 at the Perth Convention & Exhibition Centre, 21 Mounts Bay Road, Perth, Western Australia.

• The AGM will also be available online at https://web.lumiagm.com/333232445.

Climate reporting and non-binding shareholder vote

• Woodside intends to put its climate reporting to a non-binding, advisory vote of shareholders at its 2024 AGM. It is intended that subsequent shareholder votes will be held at three-year intervals, except in exceptional circumstances.

Half-year report

• Woodside’s half-year report 2023 will be released on Tuesday, 22 August 2023.

Page 4 of 15

Contacts:

INVESTORS   Matthew Turnbull (Group) M: +61 410 471 079   Sarah Peyman (Australia) M: +61 457 513 249   Rohan Goudge (US) M: +1 (713) 679-1550   E: investor@woodside.com MEDIA   Christine Forster M: +61 484 112 469 E: christine.forster@woodside.com

This announcement was approved and authorised for release by Woodside’s Disclosure Committee.

Page 5 of 15

Production summary

		Three months ended						Year to date
		Mar 2023		Dec 2022		Mar 2022		Mar 2023		Mar 2022
AUSTRALIA
LNG
North West Shelf	Mboe		9,673		9,564		4,612		9,673		4,612
Pluto2	Mboe		12,154		12,124		9,326		12,154		9,326
Wheatstone	Mboe		2,456		2,596		2,408		2,456		2,408
Total	Mboe		24,283		24,284		16,346		24,283		16,346
Pipeline gas
Bass Strait	Mboe		3,133		4,883		—		3,133		—
Other3	Mboe		3,037		3,470		753		3,037		753
Total	Mboe		6,170		8,353		753		6,170		753
Crude oil and condensate
North West Shelf	Mbbl		1,684		1,711		806		1,684		806
Pluto2	Mbbl		961		982		745		961		745
Wheatstone	Mbbl		408		506		421		408		421
Bass Strait	Mbbl		777		935		—		777		—
Macedon & Pyrenees	Mbbl		631		692		1,398		631		1,398
Ngujima-Yin	Mbbl		869		1,890		425		869		425
Okha	Mbbl		431		598		—		431		—
Total	Mboe		5,761		7,314		3,795		5,761		3,795
NGL4
North West Shelf	Mbbl		292		307		181		292		181
Pluto2	Mbbl		50		52		6		50		6
Bass Strait	Mbbl		723		1,187		—		723		—
Total	Mboe		1,065		1,546		187		1,065		187
Total Australia5	Mboe		37,279		41,497		21,081		37,279		21,081

² Q1 2023 includes 2.70 MMboe of LNG, 0.11 MMboe of condensate and 0.05 MMboe of NGL, Q4 2022 includes 2.39 MMboe of LNG, 0.10 MMboe of condensate and 0.05 MMboe of NGL and Q1 2022 includes 0.32 MMboe of LNG and 0.01 MMboe of condensate processed at the Karratha Gas Plant (KGP) through the Pluto-KGP Interconnector.

³ Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

⁴ Natural gas liquids (NGL) include LPG, ethane, propane and butane.

⁵ Q1 2023 includes 0.31 MMboe, Q4 2022 includes 0.31 MMboe and Q1 2022 includes 0.03 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.

Page 6 of 15

		Three months ended						Year to date
		Mar 2023		Dec 2022		Mar 2022		Mar 2023		Mar 2022
INTERNATIONAL
Pipeline gas
Gulf of Mexico	Mboe		330		409		—		330		—
Trinidad & Tobago	Mboe		2,236		1,952		—		2,236		—
Other6	Mboe		30		—		—		30		—
Total	Mboe		2,596		2,361		—		2,596		—
Crude oil and condensate
Atlantis	Mbbl		2,696		3,229		—		2,696		—
Mad Dog	Mbbl		939		1,165		—		939		—
Shenzi	Mbbl		2,596		2,517		—		2,596		—
Trinidad & Tobago	Mbbl		297		361		—		297		—
Other6	Mbbl		39		81		—		39		—
Total	Mboe		6,567		7,353		—		6,567		—
NGL7
Gulf of Mexico	Mbbl		331		390		—		331		—
Other6	Mbbl		17		—		—		17		—
Total	Mboe		348		390		—		348		—
Total International	Mboe		9,511		10,104		—		9,511		—
Total production	Mboe		46,790		51,601		21,081		46,790		21,081

⁶ Overriding royalty interests held in the Gulf of Mexico (GoM) for several producing wells.

⁷ Natural gas liquids (NGL) include LPG, ethane, propane and butane.

Page 7 of 15

Product sales

		Three months ended						Year to date
		Mar 2023		Dec 2022		Mar 2022		Mar 2023		Mar 2022
AUSTRALIA
LNG
North West Shelf	Mboe		10,564		9,000		5,012		10,564		5,012
Pluto8	Mboe		11,310		12,189		9,433		11,310		9,433
Wheatstone9	Mboe		2,350		2,360		2,521		2,350		2,521
Total	Mboe		24,224		23,549		16,966		24,224		16,966
Pipeline gas
Bass Strait	Mboe		3,082		4,725		—		3,082		—
Other	Mboe		2,939		3,524		748		2,939		748
Total	Mboe		6,021		8,249		748		6,021		748
Crude oil and condensate
North West Shelf	Mbbl		1,089		1,989		618		1,089		618
Pluto8	Mbbl		614		856		472		614		472
Wheatstone	Mbbl		350		684		289		350		289
Bass Strait	Mbbl		82		1,115		—		82		—
Ngujima-Yin	Mbbl		1,141		1,753		1,336		1,141		1,336
Okha	Mbbl		653		—		—		653		—
Pyrenees	Mbbl		518		1,142		—		518		—
Total	Mboe		4,447		7,539		2,715		4,447		2,715
NGL10
North West Shelf	Mbbl		170		228		—		170		—
Pluto8	Mbbl		182		—		—		182		—
Bass Strait	Mbbl		1,109		672		—		1,109		—
Total	Mboe		1,461		900		—		1,461		—
Total Australia	Mboe		36,153		40,237		20,429		36,153		20,429

⁸ Processing of volumes commenced at the Karratha Gas Plant via the Pluto-KGP Interconnector in 2022.

⁹ Includes periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.06 MMboe in Q1 2023, 0.03 MMboe in Q4 2022 and -0.18 MMboe in Q1 2022.

¹⁰ Natural gas liquids (NGL) include LPG, ethane, propane and butane.

Page 8 of 15

		Three months ended						Year to date
		Mar 2023		Dec 2022		Mar 2022		Mar 2023		Mar 2022
INTERNATIONAL
Pipeline gas
Gulf of Mexico	Mboe		343		343		—		343		—
Trinidad & Tobago	Mboe		2,295		1,969		—		2,295		—
Other11	Mboe		7		4		—		7		—
Total	Mboe		2,645		2,316		—		2,645		—
Crude oil and condensate
Atlantis	Mbbl		2,668		3,091		—		2,668		—
Mad Dog	Mbbl		941		1,098		—		941		—
Shenzi	Mbbl		2,673		2,245		—		2,673		—
Trinidad & Tobago	Mbbl		413		130		—		413		—
Other11	Mbbl		63		59		—		63		—
Total	Mboe		6,758		6,623		—		6,758		—
NGL12
Gulf of Mexico	Mbbl		342		422		—		342		—
Trinidad & Tobago	Mbbl		—		—		—		—		—
Other11	Mbbl		4		2		—		4		—
Total	Mboe		346		424		—		346		—
Total International	Mboe		9,749		9,363		—		9,749		—
MARKETING
LNG13	Mboe		4,483		2,625		3,338		4,483		3,338
Total	Mboe		4,483		2,625		3,338		4,483		3,338
Total Marketing	Mboe		4,483		2,625		3,338		4,483		3,338
Total sales	Mboe		50,385		52,225		23,767		50,385		23,767

¹¹ Overriding royalty interests held in the GoM for several producing wells.

¹² Natural gas liquids (NGL) include LPG, ethane, propane and butane.

¹³ Purchased LNG volumes sourced from third parties.

Page 9 of 15

Revenue (US$ million)

	Three months ended						Year to date
	Mar 2023		Dec 2022		Mar 2022		Mar 2023		Mar 2022
AUSTRALIA
North West Shelf		1,270		1,260		636		1,270		636
Pluto		1,131		1,666		829		1,131		829
Wheatstone14		324		383		267		324		267
Bass Strait		211		363		—		211		—
Macedon		51		54		—		51		—
Ngujima-Yin		100		164		148		100		148
Okha		56		—		—		56		—
Pyrenees		50		118		—		50		—
INTERNATIONAL
Atlantis		199		263		—		199		—
Mad Dog		68		87		—		68		—
Shenzi		199		188		—		199		—
Trinidad & Tobago		136		112		—		136		—
Other15		5		6		—		5		—
Marketing revenue16		479		431		479		479		479
Total sales revenue17		4,279		5,095		2,359		4,279		2,359
Processing revenue		47		48		35		47		35
Shipping and other revenue		4		17		1		4		1
Total revenue		4,330		5,160		2,395		4,330		2,395

Realised prices

			Three months ended							Three months ended
	Units		Mar 2023		Dec 2022		Mar 2022		Units	Mar 2023		Dec 2022		Mar 2022
LNG produced18		$/MMBtu		16.7		20.3		14.6	$/boe		105		128		93
LNG traded19		$/MMBtu		16.7		24.2		22.6	$/boe		105		153		144
Pipeline gas									$/boe		38		43		26
Oil and condensate		$/bbl		76		82		109	$/boe		76		82		109
NGL		$/bbl		51		36		—	$/boe		51		36		—
Average realised price									$/boe		85		98		100
Dated Brent									$/bbl		81		89		101
JCC (lagged three months)									$/bbl		100		113		80
WTI									$/bbl		76.1		82.8		94.3
JKM									$/MMBtu		26.0		38.6		31.2
TTF									$/MMBtu		24.7		45.0		32.6

• Average realised price was A$6.9/GJ in Western Australia, A$11.9/GJ in east coast Australia and $7.2/Mcf for International in Q1 2023.

¹⁴ Q1 2023 includes $3 million, Q4 2022 includes $2 million and Q1 2022 includes -$20 million recognised in relation to periodic adjustments reflecting the arrangements governing Wheatstone LNG sales. These amounts will be included within other income/(expenses) in the financial statements rather than operating revenue.

¹⁵ Overriding royalty interests held in GoM for several producing wells.

¹⁶ Values include revenue generated from purchased LNG volumes, as well as the marketing margin on the sale of Woodside’s produced liquids portfolio. Hedging impacts are excluded.

¹⁷ Total sales revenue excludes all hedging impacts.

¹⁸ Realised prices include the impact of periodic adjustments reflecting the arrangements governing Wheatstone LNG sales.

¹⁹ Excludes any additional benefit attributed to produced LNG through third-party trading activities.

Page 10 of 15

Expenditure (US$ million)

	Three months ended						Year to date
	Mar 2023		Dec 2022		Mar 2022		Mar 2023		Mar 2022
Exploration and evaluation expense
Exploration and evaluation expensed20		52		239		7		52		7
Permit amortisation		2		3		1		2		1
Total		54		242		8		54		8
Capital expenditure
Exploration and evaluation capitalised21,22		37		8		5		37		5
Oil and gas properties		1,279		1,342		757		1,279		757
Total		1,316		1,350		762		1,316		762
Trading costs		385		260		351		385		351

Key project expenditure (US$ million)

	Three months ended						Year to date
	Mar 2023		Dec 2022		Mar 2022		Mar 2023		Mar 2022
Capital expenditure
Scarborough23		626		599		447		626		447
Sangomar		279		290		242		279		242

²⁰ Q4 2022 includes $39m relating to the write-off of capitalised exploration costs due to the relinquishment of exploration permit acreage at Sangomar.

²¹ 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.

²² Project final investment decisions result in amounts of previously capitalised exploration and evaluation expense (from current and prior years) being transferred to oil and gas properties. This table does not reflect the impact of such transfers.

²³ Scarborough key project expenditure includes Scarborough offshore, Pluto Train 2, Pluto Train 1 modification and Train 2 tie-in spend. Prior period comparatives have been restated to include Pluto Train 1 modification and Train 2 tie-in spend of $13m in Q1 2022 and $20m in Q4 2022.

Page 11 of 15

Exploration

• In the US Gulf of Mexico (GoM) Woodside was the highest bidder on 12 leases in lease sale 259 with the final lease award pending regulatory approval. The bids were concentrated in the central GoM Miocene and western GoM Paleogene trends. Two of the 12 bids were joint bids with Oxy, in which Woodside would hold a 40% non-operating interest.²⁴

• In Egypt, the regulator has approved Woodside’s acquisition of a 27% interest in two non-operated blocks in the Herodotus Basin.

• Woodside signed an option agreement to acquire at least a 56% interest in Namibia Petroleum Exploration License 87, located in the Orange Basin offshore Namibia. The decision to exercise the option will follow evaluation of seismic data acquired as part of the agreement.

Exploration or appraisal wells drilled

Region	Permit area	Well	Target	Interest (%)	Spud date	Water depth (m)	Planned well depth (m)25	Remarks
Gulf of Mexico	GC 868	Mad Dog SWX4	Oil	23.9% Non-operator	12 March 2023	1,331	7,437	Drilling ongoing

Permits and licences

Key changes to permit and licence holding during the quarter ended 31 March 2023 are noted below.

Region	Permits or licence areas	Change in interest (%)	Current interest (%)	Remarks
Egypt – Herodotus Basin	North Sidi Barrani Offshore (Block 2)	27	27	Non-operated
Egypt – Herodotus Basin	North El Dabaa Offshore (Block 4)	27	27	Non-operated

Seismic and geophysical survey activity

Region	Field	Permits or licence areas		Remarks
Namibia	PEL 87 – Orange Basin		Deep Water PEL 87 License	Acquisition of ~6,800 km2 of 3D is ongoing

²⁴ Woodside was the highest bidder on blocks AC125, AC126, AT133, GC173, GC210, GC211, GC406, GC407, GC450, GC495 at 100% working interest (WI) and blocks GC598, GC642 at 40% WI.

²⁵ Well depths are referenced to the rig rotary table.

Page 12 of 15

Production rates

Average daily production rates (100% project) for the quarter ended 31 March 2023:

				Production rate (100% project, Mboe/d)
	Woodside share26			Mar 2023		Dec 2022		Remarks
AUSTRALIA
NWS Project
LNG		31.62	%		340		340
Crude oil and condensate		31.61	%		59		61
NGL		31.55	%		10		11
Pluto LNG
LNG		90.00	%		117		118
Crude oil and condensate		90.00	%		11		11
Pluto-KGP Interconnector
LNG		100.00	%		30		26
Crude oil and condensate		100.00	%		1		1
NGL		100.00	%		1		1
Wheatstone27
LNG		11.94	%		229		238
Crude oil and condensate		15.07	%		30		33
Bass Strait
Pipeline gas		42.30	%		82		115		Production was lower due to seasonal demand and planned onshore and offshore maintenance activities.
Crude oil and condensate		48.71	%		18		21
NGL		42.94	%		19		26
Australia Oil
Ngujima-Yin		60.00	%		16		34		Production was lower due to a planned maintenance turnaround.
Okha		50.00	%		10		13
Pyrenees		64.06	%		11		11
Other
Pipeline gas28					34		38

²⁶ Woodside share reflects the net realised interest for the period.

²⁷ The Wheatstone asset processes gas from several offshore gas fields, including the Julimar and Brunello fields, for which Woodside has 65% participating interest and is the operator.

²⁸ Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

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				Production rate (100% project, Mboe/d)
	Woodside share29			Mar 2023		Dec 2022		Remarks
INTERNATIONAL
Atlantis
Crude oil and condensate		38.50	%		78		91	Production was lower due to execution of a planned well intervention campaign.
NGL		38.50	%		5		6
Pipeline Gas		38.50	%		6		9
Mad Dog
Crude oil and condensate		20.86	%		50		62	Production was lower due to execution of a planned well intervention campaign.
NGL		20.86	%		2		2
Pipeline Gas		20.86	%		1		1
Shenzi
Crude oil and condensate		64.39	%		45		42
NGL		64.39	%		2		2
Pipeline Gas		64.39	%		1		1
Trinidad & Tobago
Crude oil and condensate		57.97	%30		6		7
Pipeline gas		44.39	%30		56		54

²⁹ Woodside share reflects the net realised interest for the period.

³⁰ Operations governed by production sharing contracts, Woodside share changes monthly.

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Forward looking statements and other conversion factors

Disclaimer and important notice

This announcement contains forward-looking statements with respect to Woodside’s business and operations, market conditions, results of operations and financial condition which reflect Woodside’s views held as at the date of this announcement. 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’, ‘estimate’, ‘expect’, ‘intend’, ‘may’, ‘target’, ‘plan’, ‘forecast’, ‘project’, ‘schedule’, ‘will’, ‘should’, ‘seek’ and other similar words or expressions. Similarly, statements that describe the objectives, plans, goals or expectations of Woodside or other statements about Woodside’s future plans for projects and the timing thereof, the implementation of Woodside’s new energy strategy and Woodside’s expectations and guidance with respect to production and certain financial results for 2023, are or may be forward-looking statements. Forward-looking statements are not guarantees of future performance and are subject to inherent known and unknown risks, uncertainties, assumptions and other factors, many of which are beyond the control of Woodside, its related bodies corporate and their respective officers, directors, employees, advisers or representatives. Important factors that could cause actual results to differ materially from those in the forward-looking statements include, but are not limited to, fluctuations in commodity prices; actual demand; currency fluctuations; geotechnical factors; drilling and production results; gas commercialisation; development progress; operating results; engineering estimates; reserve estimates; loss of market; industry competition; environmental risks; climate related risks; physical risks; legislative, fiscal and regulatory developments; changes in accounting standards; economic and financial markets conditions in various countries and regions; political risks; project delay or advancement; regulatory approvals; the impact of armed conflict and political instability (such as the ongoing conflict in Ukraine) on economic activity and oil and gas supply and demand; the effect of future regulatory or legislative actions on Woodside or the industries in which it operates, including potential changes to tax laws; as well as general economic conditions, inflationay conditions, prevailing exchange rates and interest rates and conditions in financial markets. Details of the key risks relating to Woodside and its business can be found in the “Risk” section of Woodside’s most recent Annual Report which was released to the Australian Securities Exchange on 27 February 2023 and in Woodside’s filings with the U.S. Securities and Exchange Commission, including Woodside’s Annual Report on Form 20-F. You should review and have regard to these risks when considering the information contained in this announcement.

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 announcement.

Investors are strongly cautioned not to place undue reliance on any forward-looking statements. Actual results or performance may vary materially from those expressed in, or implied by, any forward-looking statements. All information included in this announcement, including any forward-looking statements, speak only as of the date of this announcement and, except as required by law or regulation, Woodside does not undertake to update or revise any information or forward-looking statements contained in this announcement, whether as a result of new information, future events, or otherwise.

All figures are Woodside share for the quarter ending 31 March 2023, unless otherwise stated.

All references to dollars, cents or $ in this presentation are to US currency, unless otherwise stated.

References to “Woodside” may be references to Woodside Energy Group Ltd or its applicable subsidiaries.

Product	Unit	Conversion factor		bbl boe Mbbl Mboe MMboe Bcf MMBtu MMscf scf	barrel barrel of oil equivalent thousand barrels thousand barrels of oil equivalent million barrels of oil equivalent billion cubic feet of gas million British thermal units million standard cubic feet of gas standard cubic feet of gas
Natural gas	5,700 scf		1 boe
Condensate	1 bbl		1 boe
Oil	1 bbl		1 boe
Natural gas liquids (NGL)	1 bbl		1 boe
Facility	Unit		LNG conversion factor
Karratha Gas Plant	1 tonne		8.08 boe
Pluto 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.

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