Woodside Releases Quarter Three 2024 Results

October 16, 2024

by [email protected]

Sangomar fuels record-breaking production

Operations

Record quarterly production of 53.1 MMboe (577 Mboe/day), up 20% from Q2 2024 due to ramp-up of Sangomar, increased uptime across operated assets including 99.9% LNG reliability at Pluto and increased seasonal domestic gas demand. Full-year production guidance has been narrowed to 189–195 MMboe.
Quarterly revenue of $3,679 million, up 21% from Q2 2024 primarily due to Sangomar cargo sales and higher average LNG prices.
Achieved nameplate capacity at Sangomar with gross production rates of 100,000 barrels per day.
Capitalised on increased gas-hub prices by selling 39% of produced LNG cargoes in the quarter on prices linked to gas hub indices.¹ Full year gas hub guidance has been increased to 33–37% of produced LNG.

Projects

The Scarborough Energy Project was 73% complete at the end of the quarter, with trunkline installation successfully completed in October. The project is on track for first LNG cargo in 2026.²
The Trion Project was 15% complete at the end of the quarter and is targeting first oil in 2028.
Completed acquisition of OCI’s Clean Ammonia Project in Beaumont, Texas for an all-cash consideration of approximately $2,350 million, with 80% paid and the remaining 20% to be paid at project completion. The project is targeting first ammonia production from 2025 and lower carbon ammonia from 2026.³

Other

Completed acquisition of Tellurian and its US Gulf Coast Driftwood LNG development opportunity in October. The project has been renamed Woodside Louisiana LNG.
Signed a sale and purchase agreement (SPA) with JERA for the supply of approximately 0.4 Mtpa LNG for 10 years.
Executed 66 PJ of Western Australian gas sales for delivery across 2025 and 2026.
Successfully completed issuance of $2 billion of senior unsecured bonds to quality debt investors in the US market, with the book peaking at almost four times oversubscribed.

PERTH, Australia–(BUSINESS WIRE)–Woodside Energy Group (ASX: WDS) (NYSE: WDS) (LSE: WDS):

Woodside CEO Meg O’Neill said:

“We would like to acknowledge the tragic death in early October of an employee of one of the construction contractors at our Clean Ammonia Project in Beaumont, Texas.

“Safety is our top priority. We are taking steps to understand the circumstances around what occurred and are working closely with local authorities, OCI and the contractor company.

“Our production for the third quarter was a record 53.1 million barrels of oil equivalent. The strong operational performance was underpinned by the accelerated ramp-up of Sangomar and exceptional performance at Pluto LNG and NWS, which recorded 99.9% and 99.2% reliability respectively.

“Our 39% exposure to LNG gas hub indices allowed us to take advantage of increased LNG spot prices in the market over the period, demonstrating the importance of maintaining a balanced and flexible portfolio.

“At Sangomar the 24-well drilling program has been completed and the project has achieved nameplate capacity of 100,000 barrels per day. Commissioning activities continue to progress as planned and start-up of gas and water injection systems is underway.

The Scarborough Energy Project in Western Australia is now 73% complete and remains on target for first LNG cargo in 2026. Installation of the offshore Scarborough gas trunkline was completed in early October.

“At the end of September we completed the acquisition of OCI’s Clean Ammonia Project in Beaumont, Texas. Subsequent to quarter end, we completed the acquisition of Tellurian and its development opportunity, now named Woodside Louisiana LNG.

“The Clean Ammonia Project is expected to produce first ammonia in 2025 and at Woodside Louisiana LNG we are targeting final investment decision (FID) readiness from the first quarter of 2025. These acquisitions expand our diverse, geographically advantaged portfolio and position Woodside to execute our strategy to thrive through the energy transition and deliver long-term value to shareholders.

“Our sale and purchase agreement with JERA for the long-term supply of LNG from Woodside’s global portfolio again evidenced the value Asian customers place on our product.

“Woodside’s commitment to the domestic market was also demonstrated by the execution of gas sales of 66 petajoules (PJ) across 2025 and 2026 in Western Australia. In eastern Australia, to date we have executed sales of 63 PJ across 2025 and 2026 under an ongoing Expression of Interest process, with further sales expected to be completed in the fourth quarter.”

¹ 16% of total equity production in the quarter was sold on prices linked to gas hub indices.

² The completion % excludes the Pluto Train 1 modifications project.

³ Production of lower carbon ammonia is conditional on supply of carbon abated hydrogen and ExxonMobil’s CCS facility becoming operational. See disclaimer and important notices on page 16 for information on “lower carbon ammonia”.

Comparative performance at a glance

			Q3 2024	Q2 2024	Change %	Q3 2023	Change %	YTD 2024	YTD 2023	Change %
Revenue		$ million	3,679	3,033	21%	3,259	13%	9,681	10,673	(9%)
Production⁴		MMboe	53.1	44.4	20%	47.8	11%	142.4	139.1	2%
	Gas	MMscf/d	2,001	1,885	6%	2,001	–	1,939	2,000	(3%)
	Liquids	Mbbl/d	226	157	44%	169	34%	180	159	13%
	Total	Mboe/d	577	488	18%	520	11%	520	510	2%
Sales		MMboe	55.8	48.0	16%	53.3	5%	149.7	152.1	(2%)
	Gas	MMscf/d	2,154	2,103	2%	2,341	(8%)	2,075	2,292	(9%)
	Liquids	Mbbl/d	228	159	43%	169	35%	182	155	17%
	Total	Mboe/d	606	528	15%	579	5%	546	557	(2%)
Average realised price		$/boe	65	62	5%	60	8%	63	69	(9%)
Capital expenditure⁵		$ million	3,033	1,233	146%	1,360	123%	5,445	4,135	32%
	Capex excl. acquisitions	$ million	1,133	1,233	(8%)	1,360	(17%)	3,545	4,135	(14%)
	Acquisitions⁶	$ million	1,900	–	100%	–	100%	1,900	–	100%

Operations

Pluto LNG

Achieved outstanding quarterly LNG reliability of 99.9%.

North West Shelf (NWS) Project

Achieved outstanding quarterly LNG reliability of 99.2%.
Successfully completed planned maintenance offshore at North Rankin Complex and an onshore LNG train at Karratha Gas Plant (KGP), and production has recommenced as planned.
Continued to pursue opportunities for third party onshore gas processing following announcement of the Western Australian Government’s updated policy allowing onshore gas exports.
Took FID on the Low-Low Pressure Operation Project at Goodwyn Alpha, aimed at increasing NWS production from the Goodwyn area reservoirs. This project is targeted for start-up in Q2 2027.
Planning to bring one LNG train offline for retirement in the fourth quarter of 2024.

⁴ Q3 2024 includes 0.28 MMboe, Q2 2024 includes 0.30 MMboe and Q3 2023 includes 0.26 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.

⁵ Includes capital additions on property plant and equipment, exploration and evaluation capitalised, other corporate spend and investment expenditure on Beaumont Clean Ammonia Project.

⁶ Acquisition of OCI’s Clean Ammonia Project in Beaumont, Texas.

Bass Strait

Safely completed the Kipper Compression Project, adding compression facilities on the West Tuna Platform, increasing production potential of existing well stock and enabling development of additional Kipper reserves.
Continued optimisation of facilities through the Gippsland Asset Streamlining project with closure of the Cobia Platform in September 2024.
Ethane power generation project successfully started up in September.

Sangomar

Achieved nameplate capacity of 100,000 barrels per day in July 2024.
Continued to receive strong interest in Sangomar crude from buyers in Europe and Asia.
The final Phase 1 well was drilled and completed in the period. The Sangomar drilling campaign is now complete marking the successful drilling and completion of 24 development wells.
Start-up of gas and water injection systems has commenced and commissioning activities are expected to continue through 2024.

Gulf of Mexico

Completed a planned shutdown on Shenzi in July 2024 which included integrity inspections and control system improvements.
Completed a planned three-well intervention campaign on Mad Dog A-Spar.
In September, Hurricanes Francine and Helene caused deferrals at our operated and non-operated GOM facilities, largely due to availability of third-party infrastructure and planned facility ramp down.

Marketing and Trading

Signed a long-term LNG SPA with JERA to supply approximately 0.4 million tonnes (six cargoes) of LNG per year over 10 years on a delivered basis, commencing in April 2026. LNG delivered under the SPA will be sourced from volumes across Woodside’s global portfolio.
Sold 39% of produced LNG at prices linked to gas hub indices in the quarter (36% year to date).⁷Full year gas hub guidance has been increased to 33–37% of produced LNG.
Executed 66 PJ of Western Australian gas sales for delivery across 2025 and 2026. Woodside continues to engage with the Western Australian domestic market on additional supply requirements for 2025, 2026 and 2027.
Woodside continued its eastern Australian Expression of Interest (EOI) process with executed sales to date already of 63 PJ across 2025 and 2026. The remaining sales under the EOI process are expected to be completed in Q4 2024.

Projects

Scarborough Energy Project

The Scarborough and Pluto Train 2 project was 73% complete at the end of the quarter.
41 of 51 Pluto Train 2 modules have been delivered to site, with 39 modules set in position at the end of the quarter.
Fabrication of the floating production unit (FPU) hull and topsides progressed, with installation of piping, electrical, and instrumentation packages continuing on the topsides and the hull entering its second dry dock in preparation for FPU integration activities in 2025.
Trunkline installation was completed subsequent to the quarter.
The drilling program continued with batch drilling of the development wells ongoing.
First steel was cut at the module yard on the Pluto Train 1 modifications project and site preparation works at the Pluto LNG facility commenced.
First LNG cargo is targeted for 2026.

⁷ 16% of total equity production in the quarter was sold on prices linked to gas hub indices (16% of total equity production year to date).

Trion

The Trion project was 15% complete at the end of the quarter.
Awarded contracts for the floating, storage and offloading vessel (FSO) bare boat charter, aviation services, and fibre optic trunkline installation.
Procurement activities continued, including delivery of long lead items to subsea equipment manufacturers.
Completed the FPU hull 90% model review and initiated FPU pre-construction activities.

Woodside Louisiana LNG (Driftwood LNG)

Subsequent to the quarter, completed acquisition of Tellurian and its US Gulf Coast Driftwood LNG development opportunity in Calcasieu Parish, Louisiana.
Woodside acquired all issued and outstanding Tellurian common stock for approximately $900 million cash, or $1.00 per share. The implied enterprise value was approximately $1,200 million.⁸
Woodside has renamed the Driftwood LNG development opportunity Woodside Louisiana LNG.
Woodside is targeting FID readiness from the first quarter of 2025.

Decommissioning

The Griffin, Stybarrow and Enfield decommissioning campaign continued with ~54 km of flexible flowlines and umbilicals recovered in the quarter, and completion of wellhead severance activities at Enfield.
The well plug and abandonment campaign at the Stybarrow field is 40% complete, with 4 wells plugged and abandoned to date.
At Mad Dog in US Gulf of Mexico, operator (BP) completed plug and abandonment of well 869-1.

Exploration and development

Calypso

Pre-front-end engineering design (FEED) engineering studies continued to mature the technical definition and cost estimate for the deepwater infield host.
Fiscal and marketing negotiations continued with various counterparties to assess the commercial options to monetise the Calypso resource.

Browse

Additional information was provided to the WA Environmental Protection Authority to support the final phase of assessment of the Browse to North West Shelf Project environmental referral.
Engineering studies on Browse to North West Shelf Project continue to optimise the upstream development concept and improve project cost and schedule certainty.

Sunrise

The Sunrise Joint Venture participants continued negotiations with the Australian and Timor-Leste Governments to progress a new Production Sharing Contract, Petroleum Mining Code and fiscal regime.
The concept study for the potential development of Greater Sunrise is expected to conclude in Q4 2024.

⁸ Includes $50 million for Tellurian’s Series C Convertible Preferred equity shares, ~$65 million of net debt, ~$20 million net working capital adjustment, ~$50 million for management and debt change of control costs and ~$135m of interim funding from signing to close. Does not include management construction incentive payment awards. The accounting treatment of the purchase price will be included in Woodside’s 2024 Annual Report and will include share purchase consideration, interim funding and other items.

Exploration

In Congo, the Niamou Marine-1 (non-operated) well reached total depth in September 2024. The well did not encounter hydrocarbons.
In September 2024, Woodside was granted Exploration Permit WA-554-P in the Barrow sub-Basin, Western Australia. WA-554-P comprises a total area of 943 km². Woodside holds a 100% working interest in the permit.
Subsequent to the period, Woodside acquired a 40% non-operated stake in ENI’s Tiba Block in the Nile Delta, Egypt.

New energy and carbon solutions

Beaumont Clean Ammonia Project

Completed OCI Clean Ammonia acquisition, comprising 100% of OCI Clean Ammonia Holding B.V., which holds its lower carbon ammonia project in Beaumont, Texas.
The acquisition was for an all-cash consideration of approximately $2,350 million, inclusive of capital expenditure through completion of phase 1 of the project. OCI is continuing to manage the construction of the project under the Construction Management Agreement.
Woodside is targeting first ammonia production from 2025 and lower carbon ammonia from 2026 following commencement of CCS operations.⁹

H2OK

Secured non-binding offtake term sheets with several customers and continued to advance pricing and volume discussions with additional offtakers.
Woodside continues to await final guidance for the 45V Clean Hydrogen Production Tax Credit.

Woodside Solar

Woodside continued working with the Western Australian Government to progress its process to develop common user transmission infrastructure required to support the proposed Woodside Solar project.

Carbon capture and storage (CCS) opportunities

Woodside was awarded two greenhouse gas assessment permits to progress CCS evaluation work:
- G-18-AP, offshore Onslow, Western Australia, as part of a joint venture with Chevron Australia New Ventures Pty Ltd; and
- G-19-AP, off the coast of Victoria, as part of the Gippsland Basin Joint Venture (GBJV).

Corporate activities

London Stock Exchange listing

Subsequent to the period, Woodside announced it will delist from the London Stock Exchange (LSE). The last day of trading of Woodside shares on the LSE will be 19 November 2024.

Funding

Woodside successfully raised $2 billion in the US market through a multi-tranche SEC registered bond in September 2024, comprising a $1.25 billion 10-year bond and a $0.75 billion 30-year bond.
Woodside converted and upsized an existing $800 million revolving facility to a new $1.2 billion 7-year syndicated term loan primarily from Asian and European banks.

⁹ Production of lower carbon ammonia is conditional on supply of carbon abated hydrogen and ExxonMobil’s CCS facility becoming operational. See disclaimer and important notices on page 18 for information on “lower carbon ammonia”.

Hedging

Woodside hedged approximately 29.3 MMboe of 2024 oil production at an average price of approximately $75.6 per barrel, with approximately 72% delivered as of 30 September 2024.
As at 30 September, Woodside had hedged approximately 18.6 MMboe of 2025 production. An additional 11.4 MMboe was subsequently added with the total for 2025 now 30 MMboe at an average price of approximately $78.75.
Woodside also has a hedging program for Corpus Christi LNG volumes designed to protect against downside pricing risk. These hedges are Henry Hub (HH) and Title Transfer Facility (TTF) commodity swaps. Approximately 88% of volumes for the remainder of 2024, 83% of 2025 and 25% of 2026 volumes have been hedged.
The year-to-date realised value of all hedged positions for as of 30 September 2024 is a pre-tax expense of approximately $70 million, with $195 million related to oil price hedges offset by $88 million profit related to Corpus Christi hedges and $37 million related to other hedge positions. Hedging losses will be included in “other expenses” in the full-year financial statements.

Climate and sustainability

Woodside released its 2023 Reconciliation Action Plan 2021-2025 (RAP) Report. The report reflects Woodside’s progress against the four pillars outlined in the RAP including Respect for Culture and Heritage, Capability and Capacity, Economic Participation, and Stronger Communities.
Subsequent to the period Woodside signed a memorandum of understanding (MOU) with the Japan Organisation for Metals and Energy Security (JOGMEC) regarding collaboration on methane emissions management.

Upcoming events 2024 – 2025

November 2024	6-7	Australia investor site visit
January 2025	22	Q4 2024 Report

2024 full-year guidance

		Prior	Current
Production	MMboe	185 – 195 (505 – 533 Mboe/day)	189 – 195 (516 – 533 Mboe/day)
Capital expenditure¹⁰	$ billion	5.0 – 5.5	4.8 – 5.2
Gas hub exposure¹¹	% of produced LNG	26 – 33	33 – 37

¹⁰ Capital expenditure includes the following participating interests; Sangomar (82%); Scarborough (90% following completion of the transaction with LNG Japan in March 2024 and 74.9% following completion of the transaction with JERA, expected in the second half of 2024), Pluto Train 2 (51%) and Trion (60%). Trion capital expenditure includes Pemex carry. This guidance assumes no change to these participating interests in 2024. This excludes the impact of any future asset sell-downs, acquisitions or other changes in equity.

¹¹ Gas hub indices include Japan Korea Marker (JKM), TTF and National Balancing Point (NBP). It excludes HH.

Production summary

		Q3 2024	Q2 2024	Q3 2023	YTD 2024	YTD 2023
Gas	MMscf/d	2,001	1,885	2,001	1,939	2,000
Liquids	Mbbl/d	226	157	169	180	159
Total	Mboe/d	577	488	520	520	510

		Q3 2024	Q2 2024	Q3 2023	YTD 2024	YTD 2023
AUSTRALIA
LNG
North West Shelf	Mboe	7,029	7,088	6,590	22,309	25,009
Pluto¹²	Mboe	12,007	11,726	12,261	35,487	33,180
Wheatstone	Mboe	2,565	1,959	2,610	6,881	7,654
Total	Mboe	21,601	20,773	21,461	64,677	65,843

Pipeline gas
Bass Strait	Mboe	4,069	3,410	4,591	9,838	11,894
Other¹³	Mboe	4,016	3,848	3,472	11,142	9,589
Total	Mboe	8,085	7,258	8,063	20,980	21,483

Crude oil and condensate
North West Shelf	Mbbl	1,265	1,260	1,278	3,937	4,508
Pluto¹²	Mbbl	966	933	976	2,830	2,636
Wheatstone	Mbbl	474	380	477	1,316	1,310
Bass Strait	Mbbl	701	503	982	1,696	2,663
Macedon & Pyrenees	Mbbl	633	107	688	849	2,078
Ngujima-Yin	Mbbl	1,231	974	1,140	3,091	2,009
Okha	Mbbl	615	491	608	1,572	1,460
Total	Mboe	5,885	4,648	6,149	15,291	16,664

NGL
North West Shelf	Mbbl	288	279	276	857	907
Pluto¹²	Mbbl	55	59	53	168	148
Bass Strait	Mbbl	1,152	941	1,380	2,925	3,294
Total	Mboe	1,495	1,279	1,709	3,950	4,349

Total Australia¹⁴	Mboe	37,066	33,958	37,382	104,898	108,339
Total Australia¹⁴	Mboe/d	403	373	406	383	397

¹² Q3 2024 includes 1.89 MMboe of LNG, 0.08 MMboe of condensate and 0.05 MMboe of NGL, Q2 2024 includes 2.18 MMboe of LNG, 0.10 MMboe of condensate and 0.06 MMboe of NGL and Q3 2023 includes 2.07 MMboe of LNG and 0.08 MMboe of condensate and 0.05 MMboe of NGL processed at the Karratha Gas Plant (KGP) through the Pluto-KGP Interconnector.

¹³ Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

¹⁴ Q3 2024 includes 0.28 MMboe, Q2 2024 includes 0.30 MMboe and Q3 2023 includes 0.26 MMboe primarily from feed gas purchased from Pluto non-operating participants processed through the Pluto-KGP Interconnector.

		Q3 2024	Q2 2024	Q3 2023	YTD 2024	YTD 2023
INTERNATIONAL
Pipeline gas
Gulf of Mexico	Mboe	327	324	350	1,011	1,029
Trinidad & Tobago	Mboe	2,289	1,736	2,413	6,528	7,372
Other¹⁵	Mboe	–	–	17	–	47
Total	Mboe	2,616	2,060	2,780	7,539	8,448

Crude oil and condensate
Atlantis	Mbbl	2,351	2,019	2,714	6,811	8,202
Mad Dog	Mbbl	2,363	2,944	2,188	8,072	4,754
Shenzi	Mbbl	2,047	2,333	2,158	6,785	7,353
Trinidad & Tobago	Mbbl	143	94	201	363	792
Sangomar	Mbbl	5,902	540	–	6,442	–
Other¹⁵	Mbbl	81	81	36	243	156
Total	Mboe	12,887	8,011	7,297	28,716	21,257

NGL
Gulf of Mexico	Mbbl	515	355	362	1,263	1,043
Other¹⁵	Mbbl	–	–	10	–	27
Total	Mboe	515	355	372	1,263	1,070

Total International	Mboe	16,018	10,426	10,449	37,518	30,775
Total International	Mboe/d	174	115	114	137	113

Total production	Mboe	53,084	44,384	47,831	142,416	139,114
Total production	Mboe/d	577	488	520	520	510

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

Product sales

		Q3 2024	Q2 2024	Q3 2023	YTD 2024	YTD 2023
Gas	MMscf/d	2,154	2,103	2,341	2,075	2,292
Liquids	Mbbl/d	228	159	169	182	155
Total	Mboe/d	606	528	579	546	557

		Q3 2024	Q2 2024	Q3 2023	YTD 2024	YTD 2023
AUSTRALIA
LNG
North West Shelf	Mboe	7,353	7,081	7,639	22,442	27,206
Pluto	Mboe	12,014	12,749	12,622	35,276	33,524
Wheatstone¹⁶	Mboe	3,048	2,264	2,541	7,901	7,203
Total	Mboe	22,415	22,094	22,802	65,619	67,933

Pipeline gas
Bass Strait	Mboe	4,163	3,508	4,506	10,241	11,701
Other¹⁷	Mboe	3,816	3,435	3,243	10,145	9,222
Total	Mboe	7,979	6,943	7,749	20,386	20,923

Crude oil and condensate
North West Shelf¹⁸	Mbbl	1,253	1,904	1,471	4,371	4,155
Pluto	Mbbl	858	1,283	1,228	2,781	2,456
Wheatstone	Mbbl	360	666	689	1,355	1,348
Bass Strait	Mbbl	662	271	1,407	1,530	2,524
Ngujima-Yin	Mbbl	1,082	1,018	708	3,099	1,849
Okha	Mbbl	618	572	1,297	1,808	1,950
Macedon & Pyrenees	Mbbl	498	–	1	994	1,551
Total	Mboe	5,331	5,714	6,801	15,938	15,833

NGL
North West Shelf	Mbbl	249	266	263	770	688
Pluto	Mbbl	52	49	32	156	287
Bass Strait	Mbbl	1,142	361	959	2,288	2,971
Total	Mboe	1,443	676	1,254	3,214	3,946

Total Australia	Mboe	37,168	35,427	38,606	105,157	108,635
Total Australia	Mboe/d	404	389	420	384	398

¹⁶ Includes periodic adjustments reflecting the arrangements governing Wheatstone LNG sales of 0.29 MMboe in Q3 2024, 0.19 MMboe in Q2 2024 and 0.16 MMboe in Q3 2023.

¹⁷ Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

¹⁸ Includes reclassification of purchased condensate volumes from NWS JV Participants to Marketing liquids of 0.16 MMboe in Q3 2023 and 0.26 MMboe in Q2 2023.

		Q3 2024	Q2 2024	Q3 2023	YTD 2024	YTD 2023
INTERNATIONAL
Pipeline gas
Gulf of Mexico	Mboe	286	336	321	908	1,005
Trinidad & Tobago	Mboe	2,004	1,606	2,574	6,067	7,569
Other¹⁹	Mboe	2	5	7	13	20
Total	Mboe	2,292	1,947	2,902	6,988	8,594

Crude oil and condensate
Atlantis	Mbbl	2,436	2,013	2,442	6,875	7,820
Mad Dog	Mbbl	2,489	3,043	2,041	8,158	4,610
Shenzi	Mbbl	2,032	2,430	2,123	6,814	7,448
Trinidad & Tobago	Mbbl	221	19	242	292	903
Sangomar	Mbbl	6,070	–	–	6,070	–
Other¹⁹	Mbbl	45	59	61	164	189
Total	Mboe	13,293	7,564	6,909	28,373	20,970

NGL
Gulf of Mexico	Mbbl	388	454	379	1,255	1,084
Other¹⁹	Mbbl	1	3	4	7	11
Total	Mboe	389	457	383	1,262	1,095

Total International	Mboe	15,974	9,968	10,194	36,623	30,659
Total International	Mboe/d	174	110	111	134	112

MARKETING²⁰
LNG	Mboe	2,077	2,593	4,329	6,756	12,344
Liquids²¹	Mboe	555	37	169	1,163	429
Total	Mboe	2,632	2,630	4,498	7,919	12,773

Total Marketing	Mboe	2,632	2,630	4,498	7,919	12,773

Total sales	Mboe	55,774	48,025	53,298	149,699	152,067
Total sales	Mboe/d	606	528	579	546	557