Third Quarter 2022 Report

RNS Number : 4899D
Woodside Energy Group Ltd
20 October 2022
 

P1#yIS1

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

 

Thursday, 20 October 2022

 

 

THIRD QUARTER REPORT FOR PERIOD ENDED 30 SEPTEMBER 2022

 

 

Delivering reliable production

· Delivered record production of 51.2 MMboe (557 Mboe/day), up 52% from Q2 2022.

· Delivered record sales volume of 57.1 MMboe, up 59% from Q2 2022.

· Delivered record revenue of $5,858 million, up 70% from Q2 2022.

· Achieved a portfolio average realised price of $102 per barrel of oil equivalent.

· Sold 24% of produced LNG at prices linked to gas hub indices.

· Upgraded full-year 2022 production guidance to 153 - 157 MMboe.

 

Executing major projects

· Commenced fabrication of subsea flowlines for the Scarborough and Pluto Train 2 projects in Western Australia, which combined are now 21% complete.

· Commenced the subsea installation campaign for the Sangomar Field Development offshore Senegal, which is now 70% complete.

 

Investing in growth

· Issued tenders for major scopes of work for the Trion oil development offshore Mexico in preparation for a potential final investment decision (FID) in 2023.

· Signed long-term marketing agreements to increase exposure to Atlantic Basin LNG and to provide LNG to the undersupplied European market.

· Received multiple greenhouse gas assessment permits for future carbon capture and storage opportunities.

· Awarded a contract to purchase electrolysers for the proposed H2OK hydrogen project in Oklahoma.

 

Delivering merger synergies

· Completed the design and implementation of the post-merger organisation.

· Initiated an exit of the Orphan Basin exploration licences offshore eastern Canada.

 

 



 

Woodside CEO Meg O'Neill said production and revenue rose in the third quarter, reflecting the first full three months of contribution from the former BHP petroleum business.

"This is our first full quarter following the merger and these results demonstrate the new, expanded Woodside is delivering what we promised: safe, reliable energy from a more diverse portfolio.

"Production for the period was 51.2 million barrels of oil equivalent (MMboe), up 52% from the second quarter and more than twice the level in the corresponding period of last year.

"Strong operational performance across the combined portfolio has allowed us to upgrade our full-year production guidance to 153 - 157 MMboe.

"Our investment in the Pluto-KGP Interconnector is creating significant value, enabling the acceleration of 2.3 MMboe of Pluto gas using available production capacity at the Karratha Gas Plant.

"Sales volume for the third quarter climbed 59% from the preceding three months to 57.1 MMboe. Revenue increased 70% to $5,858 million, reflecting both higher sales volume and average portfolio realised price, which rose 7% to $102 per barrel of oil equivalent.

"Work on our major projects progressed to plan. The first stage of the Pluto Train 2 construction accommodation village in Karratha has been completed and fabrication of the subsea flowlines for the development of Scarborough commenced.

"Overall, the Scarborough and Pluto Train 2 projects combined were 21% complete at the end of the quarter and remain on track for targeted first LNG cargo in 2026.

"At Sangomar the subsea installation campaign began in September and development drilling progressed, with six of the planned 23 wells now complete. The project was 70% complete at quarter end with first oil targeted for the second half of 2023.

"Two long-term marketing deals signed during the quarter will strengthen Woodside's trading position in the Atlantic Basin. Woodside entered into a long-term sale and purchase agreement (SPA) with Uniper Global Commodities to supply LNG from our global portfolio from 2023 into Europe, where buyers are urgently seeking alternatives to Russian gas. We also signed an SPA for supply from the proposed Commonwealth LNG export facility in Louisiana.

"We announced plans for the Hydrogen Refueller @H2Perth, a self-contained hydrogen production, storage and refuelling station, which would assist in stimulating the hydrogen economy in Western Australia.

"We also awarded a contract in October for electrolysers for the proposed H2OK hydrogen project, a significant milestone towards our targeted final investment decision in 2023. Front-end engineering design activities for H2OK are well advanced.

"Woodside's plans to build carbon capture and storage capability progressed during the quarter with the award of a greenhouse gas assessment permit over the Calliance field in August. We are also participating in joint ventures which were awarded greenhouse gas assessment permits in the Northern Carnarvon and Bonaparte basins.

"We took decisive action to initiate an exit from our exploration position in the Orphan Basin , offshore Canada, consistent with our exploration focus on clear pathways to commercialisation," she said.

 

Comparative performance at a glance

 

 


Q3 2022

Q2 2022

Change %

Q3 2021

Change %

Production

MMboe

Mboe/day

51.2

557

33.8

371

51.7

22.2

241

131.0

Sales

MMboe

57.1

35.8

59.3

26.0

119.6

Revenue

$ million

5,858

3,438

70.4

1,574

272.2

 

Development activities

Scarborough and Pluto Train 2

· Construction works for Pluto Train 2 progressed safely and the first stage of the construction accommodation village in Karratha, Western Australia, was completed in August 2022.

· Pipeline manufacturing is 46% complete.

· Fabrication of the subsea flowlines commenced in August 2022.

· Assessment by regulators of secondary environmental approvals continued for offshore execution activities.

· The projects combined were 21% complete at the end of the period and are targeting first LNG cargo in 2026.

 

Sangomar Field Development Phase 1

· The subsea installation campaign began in September 2022.

· The development drilling program progressed with six of 23 wells completed.

· Construction and conversion activities for the floating production storage and offloading (FPSO) facility progressed in preparation for the planned relocation of the facility to Singapore in Q4 2022 to complete the topsides integration and commissioning.

· The project was 70% complete at the end of the period and first oil is targeted for the second half of 2023.

 

Mad Dog Phase 2

· The operator is working through project commissioning issues, which will delay start up until 2023. Woodside will provide an update as further information becomes available.

 

Trion

· Woodside continued to optimise the execution and contracting plans in preparation for a potential FID in 2023.

· The floating production unit (FPU) bid package was issued to prospective contractors and other key scopes of work bid packages will be issued in Q4 2022 in order to provide cost and schedule predictability to support FID.

· The field development plan (FDP) has matured and engagements are planned with the regulator ahead of FDP submission in 2023.

 

Browse

· Woodside was awarded a greenhouse gas assessment permit over the Calliance field in August 2022 and technical work for a carbon capture and storage solution is maturing.

· The final Environment Impact Statement was published in September 2022.

 

Sunrise

· The Sunrise Joint Venture and Australian and Timor-Leste Governments held the third Greater Sunrise trilateral meeting for this year to progress a new production sharing contract (PSC).

 

Operational overview

Production

· Woodside achieved a significant increase in production in Q3 2022 compared to the prior quarter, primarily due to the contribution of the former BHP Petroleum (BHPP) assets for the full quarter and the completion of planned turnarounds at several assets.

 

Subsea tie-back projects

· In Western Australia, the drilling and completions campaign for the Xena-02 well was completed and ready for start-up (RFSU) remains on track for Q4 2022. The Pyxis Hub project was 97% complete at the end of the period.

· Drilling commenced for the second development well of the Shenzi North project in the Gulf of Mexico. The project was 30% complete at the end of the period and is targeting first oil in 2024.

 

Bass Strait

· Woodside's Bass Strait production has responded positively to challenging market conditions by continuing to meet demand in the east coast gas market.

· The Gippsland Basin Joint Venture (GBJV) executed a long-term supply agreement with BOC for the supply of 60,000 tonnes per annum of carbon dioxide (CO2) from the GBJV's Longford Gas Conditioning Plant. The CO2 will be captured and transformed into products for use in the food, beverage, hospitality, manufacturing and medical industries.

 

Aiming for Zero Methane Emissions Initiative

· Woodside was the first Australasian company to sign the Aiming for Zero Methane Emissions Initiative, committing to strive to reach near-zero methane emissions from its operated assets by 2030.

 

New energy

Ammonia supply chain

· Woodside signed a joint research agreement to undertake a feasibility study into the development of an ammonia supply chain from Australia to Japan. Other parties to the agreement include Japan Oil, Gas and Metals National Corporation, Marubeni Corporation, Hokuriku Electric Power Company, Kansai Electric Power Company, Tohoku Electric Power Company, and Hokkaido Electric Power Company. This is consistent with our approach of collaborating along the value chain to create early markets for our new energies products.

 

Hydrogen Refueller @H2Perth

· Woodside announced plans for a proposed self-contained hydrogen production, storage and refuelling station, located in the Rockingham Industry Zone in Western Australia.

 

H2O K

· Woodside awarded a contract to Nel Hydrogen Electrolyser AS in October 2022 for alkaline electrolyser equipment with capacity of 60 tonnes per day of liquid hydrogen. H2OK is designed for 90 tonnes per day.

· FEED activities were 84% complete at the end of the period.

 

Carbon management

· Woodside was awarded greenhouse gas assessment permits to progress carbon capture and storage (CCS) evaluation work:

off the north west coast of Western Australia, as part of the Northern Carnarvon Basin CCS Joint Venture

off the north western coast of the Northern Territory, as part of the Bonaparte CCS Assessment Joint Venture.

 

Marketing

Commonwealth LNG

· Woodside announced the conversion of its non-binding heads of agreement with Commonwealth LNG into two binding LNG sale and purchase agreements (SPAs).

· The SPAs are for the supply of 2.0 million tonnes per annum (Mtpa) of LNG over 20 years from Commonwealth's LNG export facility under development in Cameron Parish, Louisiana. Woodside's offtake obligation can be reduced or even eliminated as Commonwealth achieves increasing thresholds of offtake commitments from other buyers. Woodside also has an option to purchase an additional 0.5 Mtpa of LNG. The SPAs will become fully effective upon the satisfaction of customary conditions including an affirmative FID on the project.

 

Uniper Global Commodities SE

· Woodside entered into a flexible long-term SPA with Uniper Global Commodities SE to supply LNG from its global portfolio into Europe, including Germany, for a term up to 2039 commencing in January 2023.

· The quantity of LNG to be supplied under the new SPA is up to twelve cargoes per year, equivalent to more than 0.8 Mtpa. Supply from September 2031 is conditional upon Uniper finalising its long-term strategic capacity bookings in north west Europe, expected by March 2023.

 

Corporate activities

Hedging

· As at 30 September 2022, Woodside has placed oil price hedges for:

approximately 17.5 MMboe of 2022 production at an average price of $74.6 per barrel of which approximately 11.6 MMboe has been delivered

approximately 21.8 MMboe of 2023 production at an average price of $74.5 per barrel.

· 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. As at 30 September 2022 and as a result of hedging and term sales, approximately 78% of Corpus Christi volumes for the remainder of 2022, approximately 72% of 2023 volumes and approximately 28% of 2024 volumes have reduced pricing risk.

· The year-to-date value of hedged positions to 30 September 2022 is a post-tax expense of approximately $500 million. Hedging losses will be included in "other expenses" in the full-year financial statements.

 

Investor Briefing Day 2022

· Woodside's Investor Briefing Day 2022 will be held in Sydney, Australia, on Thursday, 1 December 2022, commencing at 09.30 AEDT / 06.30 AWST (16.30 CST on Wednesday, 30 November 2022).

· A live webcast of the event will be available at https://webcast.openbriefing.com/9173/

 

2022 full-year guidance

 



Prior

Current

Production

MMboe

145 - 153

153 - 157

Exploration expenditure[1]

$ million

400 - 500

500 - 600

Capital expenditure[2]

$ million

4,300 - 4,800

4,000 - 4,300

Gas hub exposure

% of produced LNG

20 - 25

No change

 

 

 

Contacts:

 

 


INVESTORS

 

Matthew Turnbull

M: +1 (713) 448-0956

M: +61 410 471 079

 

Derek Lau

M: +61 413 286 251

 

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.

Production summary



Three months ended

Year to date



Sep
2022

Jun
2022

Sep
2021

Sep
2022

Sep
2021







LNG







North West Shelf

Mboe

9,694

5,826

4,566

20,132

15,599

Pluto 0F [3]

Mboe

12,458

12,328

10,082

34,112

29,878

Wheatstone

Mboe

2,556

1,645

2,432

6,609

7,867

Total

Mboe

24,708

19,799

17,080

60,853

53,344

 







Pipeline gas

 






Bass Strait

Mboe

6,481

2,353

8,834

Other 1F [4]

Mboe

3,389

1,692

602

5,834

1,904

Total

Mboe

9,870

4,045

602

14,668

1,904








Crude oil and condensate







North West Shelf

Mbbl

1,750

1,104

743

3,660

2,570

Pluto3

Mbbl

990

967

756

2,702

2,267

Wheatstone

Mbbl

494

277

519

1,192

1,796

Bass Strait

Mbbl

1,229

441

1,670

Macedon

Mbbl

1

-

-

1

-

Ngujima-Yin

Mbbl

1,464

2,275

1,916

5,137

5,199

Okha

Mbbl

653

444

448

1,522

1,064

Pyrenees

Mbbl

601

223

824

Total

Mboe

7,182

5,731

4,382

16,708

12,896








NGL 2 [5]







North West Shelf

Mbbl

324

228

117

733

370

Pluto3

Mbbl

52

60

118

Bass Strait

Mbbl

1,554

503

2,057

Total

Mboe

1,930

791

117

2,908

370








Total Australia

Mboe

43,690

30,366

22,181

95,137

68,514

 

 

 






NB: Future reporting will combine the crude oil and condensate lines for Macedon and Pyrenees. This will apply from the Fourth Quarter 2022 Report.

 



 



Three months ended

Year to date



Sep
2022

Jun
2022

Sep
2021

Sep
2022

Sep
2021

INTERNATIONAL

 

 

 

 

 

 

Pipeline gas







Atlantis


Mboe

115

87

-

202

Mad Dog


Mboe

20

10

-

30

-

Shenzi


Mboe

84

25

-

109

-

Trinidad & Tobago


Mboe

2,102

829

-

2,931

-

Total

Mboe

2,321

951

-

3,272

-

 

 






Crude oil and condensate







Atlantis

Mbbl

1,257

987

-

2,244

-

Mad Dog

Mbbl

838

411

-

1,249

-

Shenzi

Mbbl

2,452

765

-

3,217

-

Trinidad & Tobago

Mbbl

365

150

-

515

-

Other 3F [6]

Mbbl

81

27

-

108

-

Total

Mboe

4,993

2,340

-

7,333

-








NGL 4 [7]







Atlantis

Mbbl

87

66

-

153

-

Mad Dog

Mbbl

31

16

-

47

-

Shenzi

Mbbl

126

37

-

163

-

Total

Mboe

244

119

-

363

-

 

 






Total International

Mboe

7,558

3,410

-

10,968

-



 

 

 

 

 

Total production

Mboe

51,248

33,776

22,181

106,105

68,514

 

NB: Future reporting will combine the pipeline gas lines for Atlantis, Mad Dog and Shenzi, and the NGL lines for Atlantis, Mad Dog and Shenzi. This will apply from the Fourth Quarter 2022 Report.



 

Product sales



Three months ended

Year to date



Sep
2022

Jun
2022

Sep
2021

Sep
2022

Sep
2021

AUSTRALIA


 

 

 

 

 

LNG


 

 

 

 

 

North West Shelf

Mboe

8,441

 5,616

 3,740

19,069

14,591

Pluto 5 [8]

Mboe

11,862

11,094

9,379

32,389

29,507

Wheatstone 6 [9]

Mboe

2,898

1,464

2,514

6,883

7,189

Total

Mboe

23,201

18,174

15,633

58,341

51,287

 


 

 

 

 

 

Pipeline gas

 

 

 

 

 

 

Bass Strait

Mboe

6,564

2,194

 - 

8,758

 - 

Other

Mboe

3,436

1,629

609

5,813

1,903

Total

Mboe

10,000

3,823

609

14,571

1,903



 

 

 

 

 

Crude oil and condensate







North West Shelf

Mbbl

2,140

1,018

682

3,776

2,014

Pluto8

Mbbl

838

1,828

990

3,138

2,160

Wheatstone

Mbbl

325

354

403

968

1,797

Bass Strait

Mbbl

1,435

333

 - 

1,768

 - 

Ngujima-Yin

Mbbl

1,502

2,436

1,825

5,274

5,098

Okha

Mbbl

1,298

619

-

1,917

810

Pyrenees

Mbbl

502

 - 

 - 

502

 - 

Total

Mboe

8,040

6,588

3,900

17,343

11,879



 

 

 

 

 

NGL 7 [10]


 

 

 

 

 

North West Shelf

Mbbl

701

 - 

 - 

701

 358

Pluto8

Mbbl

 - 

 - 

 - 

 - 

 - 

Bass Strait

Mbbl

1,999

213

 - 

2,212

 - 

Total

Mboe

2,700

213

 - 

2,913

 358



 

 

 

 

 

Total Australia

Mboe

43,941

28,798

20,142

93,168

65,427

 

 

 

 

 

 

 

 



 



Three months ended

Year to date



Sep
2022

Jun
2022

Sep
2021

Sep
2022

Sep
2021

INTERNATIONAL

 

 

 

 

 

 

Pipeline gas


 

 

 

 

 

Atlantis

Mboe

118

95

 - 

213

 - 

Mad Dog

Mboe

19

11

 - 

30

 - 

Shenzi

Mboe

77

21

 - 

98

 - 

Trinidad & Tobago

Mboe

2,118

836

 - 

2,954

 - 

Other 8 [11]

Mboe

9

3

 - 

12

 - 

Total

Mboe

2,341

966

 - 

3,307

 - 

 

 

 

 

 

 

 

Crude oil and condensate


 

 

 

 

 

Atlantis

Mbbl

1,466

883

 - 

2,349

 - 

Mad Dog

Mbbl

891

379

 - 

1,270

 - 

Shenzi

Mbbl

2,636

718

 - 

3,354

 - 

Trinidad & Tobago

Mbbl

443

204

 - 

647

 - 

Other 1 1

Mbbl

77

28

 - 

105

-

Total

Mboe

5,513

2,212

 - 

7,725

 - 



 

 

 

 

 

NGL 9 [12]


 

 

 

 

 

Atlantis

Mbbl

96

67

 - 

163

 - 

Mad Dog

Mbbl

37

18

 - 

55

 - 

Shenzi

Mbbl

143

39

 - 

182

 - 

Trinidad & Tobago

Mbbl

 - 

 - 

 - 

 - 

 - 

Other 1 1

Mbbl

4

2

 - 

6

 

Total

Mboe

280

126

 - 

406

 - 



 

 

 

 

 

Total International

Mboe

8,134

3,304

 - 

11,438

 - 

 

 

 

 

 

 

 

MARKETING

 

 

 

 

 

 

LNG

 

 

 

 

 

 

Trading 1 [13]

Mboe

5,023

3,741

5,858

12,102

14,453

Total

Mboe

5,023

3,741

5,858

12,102

14,453



 

 

 

 

 

Total Marketing

Mboe

5,023

3,741

5,858

12,102

14,453



 

 

 

 

 

Total sales

Mboe

57,098

35,843

26,000

116,708

79,880

 

NB: Future reporting will combine the pipeline gas lines for Atlantis, Mad Dog and Shenzi, and the NGL lines for Atlantis, Mad Dog and Shenzi. This will apply from the Fourth Quarter 2022 Report.

 

 



 

Revenue (US$ million)


Three months ended

Year to date


Sep
2022

Jun
2022

Sep
2021

Sep
2022

Sep
2021

AUSTRALIA

 

 

 

 

 

  North West Shelf

1,081

523

244

2,240

751

  Pluto 11 [14]

1,716

1,286

642

3,831

1,572

  Wheatstone 12 [15]

300

160

162

727

493

  Bass Strait

656

232

 - 

888

 - 

  Macedon

41

16

 - 

57

 - 

  Ngujima-Yin

162

288

146

598

393

  Okha

124

67

-

191

54

  Pyrenees

69

1

 - 

70

 - 

 

 

 


 


INTERNATIONAL

 

 


 


  Atlantis

134

109

 - 

243

 - 

  Mad Dog

81

44

 - 

125

 - 

  Shenzi

249

83

 - 

332

 - 

  Trinidad & Tobago

143

66

 - 

209

 - 

  Other 13 [16]

7

3

 - 

10

 - 

 

 

 


 


Marketing (trading) revenue 14 [17]

1,043

511

337

2,033

674

 

 

 


 


Total sales revenue

5,806

3,389

1,531

11,554

3,937

 

 

 


 


Processing revenue

50

42

36

127

106


 

 


 


Shipping and other revenue

2

7

7

10

24

 

 

 

 

 


Total revenue

 5,858

3,438

1,574

11,691

4,067

 

 

 

Realised prices

 

 

 

 Three months ended

 

 Three months ended

 

 

Units

Sep 2022

Jun 2022

Sep 2021

Units

Sep 2022

Jun 2022

Sep

2021

 

LNG produced 15 [18]

$/MMBtu

19.1

13.8

9.7

$/boe

117

87

56

 

LNG traded 16 [19]

$/MMBtu

32.7

21.5

9.9

$/boe

207

137

58

 

Pipeline gas





$/boe

49

57

17

 

Oil and condensate

$/bbl

95

115

77

$/boe

95

115

77

 

NGL

$/bbl

48

48

-

$/boe

48

48

 - 

 










 

Average realised price




$/boe

102

95

59

 










 

Dated Brent





$/bbl

101

114

73

 

JCC (lagged three months)




$/bbl

111

86

67

 WTI





$/bbl

91.6

108.4

70.6

 

 

JKM





$/MMBtu

36.0

31.3

13.2

 

TTF





$/MMBtu

50.9

31.6

12.6

 

 

Expenditure (US$ million)


Three months ended

Year to date


Sep

2022

Jun

2022

Sep

2021

Sep

2022

Sep

2021

Exploration and evaluation expense

 

 

 

 

 

Exploration and evaluation expensed 17F [20]

181

27

11

215

99

Permit amortisation

5

2

-

8

2

Total

186

29

11

223

101

 

 

 

 

 

 

Capital expenditure

 

 

 

 

 

Exploration and evaluation capitalised 18F [21] , 19F [22]

101

99

111

223

Oil and gas properties

1,056

748

622

2,561

1,218

Total

1,157

753

721

2,672

1,441

 

 

 

 

 

 

Trading costs

727

442

 

1,517

 

 

 

 

Key project expenditure (US$ million)


Three months ended

Year to date


Sep

2022

Jun

2022

Sep

2021

Sep

2022

Sep

2021

Capital expenditure

 

 

 

 

 

Scarborough and Pluto Train 2

424

332

90

1,190

209

Sangomar

278

207

435

727

775

 



 

Exploration

Permits and licences

Key changes to permit and licence holding during the quarter ended 30 September 2022 are noted below.

 

Region

Permits or licence areas

Change in interest (%)

Current interest (%)

Remarks

 

Australia

WA-522-P

(100)

-

Permit surrendered

 

Myanmar

AD-1, AD-8

(50)

-

Relinquished, formalities pending

 

Gulf of Mexico

AC 34, AC 35, AC 36, AC 39, AC 78, AC 79, AC 80, AC 81, AC 82, AC 83, AC 125, AC 126, AC 127, AC 170, EB 655, EB 656, EB 699, EB 700, EB 701, EB 742, EB 785, EB 786, EB 830, EB 870, EB 871, EB 872, EB 914, EB 915

(30)

70

Farm down


Gulf of Mexico

EB 566, EB 567, EB 610, EB 611, GB 663, GB 664, GB 687

100

100

Lease sale 257


 

· The Hoodoo Gulf of Mexico Participation Agreement was executed on 22 August 2022, resulting in Oxy acquiring a 30% interest in 28 blocks operated by Woodside. The Hoodoo-1 well spudded in October 2022.

· As part of ongoing rationalisation of Woodside's exploration portfolio, Woodside has initiated an exit from operated licence EL1157 (100% equity) in Newfoundland and Labrador, and operated licence EL1158 (100% equity) in the Orphan Basin offshore eastern Canada. The decision to exit these exploration licences is expected to impact 2022 net profit after tax (NPAT) by approximately US$140 million. These costs will be included in "exploration and evaluation expense" in the full-year financial statements.

· Drilling of the SNE North-2 well offshore Senegal completed in October 2022. The well targeted a near field tie-back opportunity to the under construction Sangomar FPSO facility. The well encountered sub-commercial quantities of hydrocarbons and was plugged and abandoned.

 

Exploration or appraisal wells drilled

Region

Permit area

Well

Target

Interest (%)

Spud date

Water depth (m)

Planned well depth (m) 20 [23]

Remarks

Gulf of Mexico

GC 826

Mad Dog SP1 exploration tail

Oil

23.9%
Non-operator

N/A 21 [24]

1,513

8,051

Drilling complete

Gulf of Mexico

GC 609

Shenzi North SN102

Oil

72%
Operator

23 July 2022

1,308

9,189

Drilling ongoing

Gulf of Mexico

MC 412

Starman-1

Oil

25%
Non-operator

9 June 2022

457

8,327

Drilling ongoing

Senegal

RSSD

SNE North-2

Oil

90%
Operator

12 September 2022

762

2,907

Drilling complete 22F [25]

 



 

Production rates

 

Average daily production rates (100% project) for the quarter ended 30 September 2022:

 

Woodside
share
23F [26]

Production rate
(100% project, Mboe/d)

Remarks



Sep

2022

Jun

2022 24F [27]


AUSTRALIA


 

 


NWS Project





LNG

 30.42%

346

311


 

Crude oil and condensate

30.45%

62

59

NGL

31.51%

12

12






Pluto LNG





LNG

90.00%

122

120


Crude oil and condensate

90.00%

11

11






Pluto-KGP Interconnector




LNG

100.00%

25

28


Crude oil and condensate

100.00%

1

1

NGL

100.00%

1

1






Wheatstone





LNG

11.53%

241

157

Production was higher following completion of the turnaround in Q2 2022.

 

Crude oil and condensate

15.98%

34

19







Bass Strait





Pipeline gas

44.93%

157

161


 

Crude oil and condensate

48.19%

28

29


NGL

48.72%

35

36







Australia Oil





Ngujima-Yin

60.00%

27

42

Production was lower due to decreased facility reliability.

Okha

50.00%

14

12


Pyrenees

63.69%

10

11







Other





Pipeline gas 25F [28]


37

36









 

 

Woodside
share
26 [29]

Production rate
(100% project, Mboe/d)

Remarks



Sep

2022

Jun

2022 27 [30]


INTERNATIONAL


 

 


Atlantis





Crude oil and condensate

38.50%

35

84

Completed approximately seven week planned turnaround.

NGL

38.50%

2

6

Pipeline Gas

38.50%

3

7







Mad Dog





Crude oil and condensate

20.86%

44

58


NGL

20.86%

2

2

Pipeline Gas

20.86%

1

1







Shenzi





Crude oil and condensate

64.39%

41

40


NGL

64.39%

2

2

Pipeline Gas

64.39%

1

1







Trinidad & Tobago





Crude oil and condensate

N/A

7

7


Pipeline gas

N/A

57

56







 



 

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. Forward-looking statements 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. These forward-looking statements include, but are not limited to, statements about Woodside's future plans for projects and the timing thereof, the implementation of Woodside's new energy strategy, Woodside's planned sell-down of interests in certain projects, Woodside's expectations and guidance with respect to production and certain financial results for full year 2022, and the effect of Woodside's anticipated exits from certain operated licences. 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; 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; Woodside's ability to identify purchasers, and to negotiate acceptable terms, for the sell-down of interests in certain projects; the effect of future regulatory or legislative actions on Woodside or the industries in which it operates, including potential changes to tax laws; inflation and government efforts to reduce inflation; increases in interest rates; and fluctuations in currency exchange rates.  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 17 February 2022 and in Woodside's filings with the U.S. Securities and Exchange Commission. You should review and have regard to these risks when considering the information contained 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 30 September 2022, 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.



[1] Includes $140 million related to the decision to exit the Orphan Basin exploration licences in Canada.

[2] Capital expenditure includes the following participating interests; Sangomar (82%); Scarborough (100%, from 1 June 2022) and Pluto Train 2 (51%). Capital expenditure excludes the benefit of Global Infrastructure Partners' additional contribution of approximately
$800 million for Pluto Train 2.

[3] Q3 2022 includes 2.35 MMboe of LNG, 0.09 MMboe of condensate and 0.05 MMboe of NGL, Q2 2022 includes 2.51 MMboe of LNG, 0.10 MMboe of condensate and 0.06 MMboe of NGL and Q3 YTD 2022 includes 5.17 MMboe of LNG, 0.20 MMboe of condensate and 0.12 MMboe of NGL processed at the Karratha Gas Plant (KGP) through the Pluto-KGP Interconnector.

[4] Includes the aggregate Woodside equity domestic gas production from all Western Australian projects.

[5] Natural gas liquids (NGL) include LPG, ethane, propane and butane.

[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.

[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 0.09 MMboe in Q3 2022, 0.06 MMboe in Q2 2022, -0.40 MMboe in Q3 2021, -0.03 MMboe in Q3 YTD 2022 and -0.60 MMboe in Q3 YTD 2021.

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

[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.

[14] Q3 YTD 2022 includes $38 million and Q3 YTD 2021 includes $32 million relating to Pluto volumes delivered into a Wheatstone sales commitment. These amounts will be included within other income in the financial statements rather than operating revenue.

[15] Q3 2022 includes $10 million, Q2 2022 includes $5 million, Q3 2021 includes -$25 million, Q3 YTD 2022 includes -$5 million and Q3 YTD 2021 includes -$36 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.

[16] Overriding royalty interests held in GOM for several producing wells.

[17] Values include cargoes from Corpus Christi, third party trades and the joint venture partners' share of Pluto upside cargoes under the transitional marketing arrangements agreement (TMAA).

[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.

[20] Exploration expense includes the reclassification of well results during the period. Includes $140 million related to the decision to exit the Orphan Basin exploration licences in Canada.

[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] Well depths are referenced to the rig rotary table.

[24] Drilling of exploration tail in existing Mad Dog SP1 well commenced 11 July 2022.

[25] Drilling completed subsequent to the period. The well encountered sub-commercial quantities of hydrocarbons.

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

[27] Standalone former BHPP assets represented at 100% rates over the month of June only.

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

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

[30] Standalone former BHPP assets represented at 100% rates over the month of June only.



This information is provided by RNS, the news service of the London Stock Exchange. RNS is approved by the Financial Conduct Authority to act as a Primary Information Provider in the United Kingdom. Terms and conditions relating to the use and distribution of this information may apply. For further information, please contact rns@lseg.com or visit www.rns.com.

RNS may use your IP address to confirm compliance with the terms and conditions, to analyse how you engage with the information contained in this communication, and to share such analysis on an anonymised basis with others as part of our commercial services. For further information about how RNS and the London Stock Exchange use the personal data you provide us, please see our Privacy Policy.
 
END
 
 
QRTXKLLFLBLBFBD
UK 100

Latest directors dealings