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BHP Group PLC (BHP)

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Wednesday 19 January, 2022

BHP Group PLC

Operational Review for Half Year Ended 31 Dec 2021

RNS Number : 8819Y
BHP Group PLC
19 January 2022
 

Release Time

IMMEDIATE

Date

19 January 2022

Release Number

02/22

BHP OPERATIONAL REVIEW
FOR THE HALF YEAR ENDED 31 DECEMBER 2021

Note: All guidance is subject to further potential impacts from COVID-19 during the 2022 financial year.

· We remained fatality free at our operated assets for the third consecutive year.

· WAIO achieved near record production for the half year and Escondida achieved record material mined, notwithstanding the impacts of significant wet weather and the COVID-19 Omicron variant on some operations. 

· Production guidance for the 2022 financial year remains unchanged for iron ore, energy coal and nickel. Full year total copper production is trending towards the low end of the guidance range, reflecting lower production guidance for Pampa Norte. Metallurgical coal guidance has been reduced as a result of significant wet weather impacts and COVID-19 related labour constraints.

· Full year unit cost guidance(1) for WAIO, Escondida and NSWEC remains unchanged. Unit cost guidance for Queensland Coal has been increased, reflecting lower expected volumes for the full year.

· Progress on the review of our lower grade metallurgical coal and thermal coal assets continues. The Cerrejón divestment to Glencore completed in January 2022 and the announced share sale agreement to divest BHP Mitsui Coal ( BMC) is expected to complete in the middle of the 2022 calendar year.

· Our potash major projects under development are tracking to plan. The Jansen shaft project is 98% complete and the Jansen Stage 1 project has commenced contract awards.

· BHP announced a final decision to unify BHP's corporate structure under its existing Australian parent company, BHP Group Limited. Shareholder meetings to vote on unification will be held on 20 January 2022. Subject to shareholder approval and UK Court sanction, unification is expected to complete by 31 January 2022.

· Completion of the proposed merger of our Petroleum business with Woodside is expected in the June 2022 quarter subject to satisfaction of conditions precedent including approval by Woodside shareholders. The half year financial results are being prepared on the basis that the Petroleum business is a discontinued operation and restated financial information for the year ended 30 June 2021 and the half year ended 31 December 2020 is provided in Attachment 1.

1

 

Production

 

Dec H21

(vs Dec H20)
 

Dec Q21

(vs Sep Q21)
 

Dec Q21 vs Sep Q21 commentary
 

Copper (kt)

742.0
(12%)

365.5
(3%)

Lower volumes at Olympic Dam due to the planned smelter maintenance campaign, completed in January 2022. This was partially offset by higher volumes at Antamina.

Iron ore (Mt)

129.4
1%

66.1
4%

Higher volumes reflecting strong supply chain performance, increased ore car availability and the continued ramp up of South Flank. This was partially offset by the impact of temporary rail labour shortages due to COVID-19 related border restrictions.

Metallurgical coal (Mt)(2)

17.7
(8%)

8.8
0%

Volumes flat due to double the amount of rainfall recorded in this quarter impacting most operations and planned maintenance in the previous quarter.

Energy coal (Mt)(3)

7.2
5%

3.0
(30%)

Lower volumes due to three times the amount of rainfall in this quarter impacting stripping and mine productivity, partially offset by mining in lower strip ratio areas.

Nickel (kt)

39.3
(15%)

21.5
21%

Higher volumes due to planned maintenance across the supply chain in the previous quarter.

Discontinued operations

Petroleum (MMboe)

53.2
5%

25.7
(7%)

Lower volumes due to reduced seasonal gas demand at Bass Strait. This was partially offset by a Shenzi infill well brought online and higher production at North West Shelf .

Group copper equivalent production decreased by 4%(4) in the December 2021 half year largely due to lower copper and metallurgical coal volumes.

 

 

2

Summary

BHP Chief Executive Officer, Mike Henry:

"BHP was fatality free at our operated assets for the third consecutive year. Our continuing focus on people and on operational reliability enabled us to achieve near record production in iron ore and to reduce the impacts of adverse weather and COVID-19 related labour constraints in our operations. Cost control remained strong across the business, in the face of a more inflationary environment. Unit cost guidance remains intact bar a change to metallurgical coal which is a function of the lowering of production guidance as a result of significant wet weather and in anticipation of Omicron headwinds in the early part of the second half of the financial year.

We completed major planned maintenance programs in our Iron Ore, Nickel West and Olympic Dam assets. In Nickel West, we achieved first saleable production of nickel sulphate crystals from the Kwinana plant, an exciting new addition to our product suite that will further enhance our offering into the battery electric vehicle market. The ramp-up of South Flank continues to progress well. The Spence Growth project is realising lower than expected recoveries and we are studying plant design modifications in order to lift recoveries to planned levels.

We continued to progress a number of actions related to our portfolio and corporate structure. We progressed the merger of our petroleum assets with Woodside and prepared for a shareholder vote on a unified corporate structure. We advanced the Jansen potash project and announced a share sale agreement of our interest in the BHP Mitsui Coal metallurgical coal joint venture. We bolstered options in future facing commodities investing in prospective copper assets in the Northern Territory and South Australia and we secured an early stage entry into a world-scale nickel sulphide resource in Tanzania.

Overall we made good progress in positioning our portfolio and performance to deliver returns for shareholders now and into the future."

3

Operational performance

Production and guidance are summarised below.

Note: All guidance is subject to further potential impacts from COVID-19 during the 2022 financial year.

Production
 

Dec
H21

 

Dec
Q21

 

Dec H21
vs
Dec H20

 

Dec Q21
vs
Dec Q20

 

Dec Q21
vs
Sep Q21

 

Previous FY22 guidance

 

Current
FY22
guidance

 

 

Copper (kt)

 742.0

 365.5

(12%)

(15%)

(3%)

1,590 - 1,760

1,590 - 1,760

Low end

  Escondida (kt)

 488.3

 244.6

(15%)

(15%)

0%

1,000 - 1,080

1,020 - 1,080

Narrowed range

  Pampa Norte (kt)

 135.8

 68.3

40%

26%

1%

330 - 370

260 - 300

Lowered

  Olympic Dam (kt)

 43.7

 14.2

(56%)

(70%)

(52%)

140 - 170

140 - 150

Narrowed range

  Antamina (kt)

 74.2

 38.4

1%

(1%)

7%

120 - 140

120 - 140

Unchanged

Iron ore (Mt)

 129.4

 66.1

1%

6%

4%

249 - 259

249 - 259

 

  WAIO (Mt)

 127.3

 65.1

(1%)

4%

5%

246 - 255

246 - 255

Unchanged

  WAIO (100% basis) (Mt)

 144.4

 73.9

0%

5%

5%

278 - 288

278 - 288

Unchanged

  Samarco (Mt)

 2.1

 1.0

>100%

>100%

(2%)

3 - 4

3 - 4

Unchanged

Metallurgical coal (Mt)(i)

 17.7

 8.8

(8%)

(7%)

0%

39 - 44

38 - 41

 

  Queensland Coal (100% basis) (Mt)

 30.7

 15.1

(10%)

(11%)

(3%)

70 - 78

68 - 72

Lowered

Energy coal - NSWEC (Mt)

 7.2

 3.0

5%

(8%)

(30%)

13 - 15

13 - 15

Unchanged

Energy coal - Cerrejón (Mt)(ii)

4.2

2.2

>100%

>100%

6%

n/a

n/a

 

Nickel (kt)

 39.3

 21.5

(15%)

(10%)

21%

85 - 95

85 - 95

Unchanged

Discontinued operations

 

 

 

 

 

 

 

 

Petroleum (MMboe)(iii)

 53.2

 25.7

5%

8%

(7%)

99 - 106

n/a

 

(i)  We announced the share sale agreement to divest our interest in BHP Mitsui Coal (BMC) in November 2021, however will continue to report BMC as part of Queensland Coal. We maintain economic and operating control of BMC until the sale has completed.

(ii)  We have ceased providing Cerrejón production guidance due to the completion of the divestment of our interest. The transaction has an effective economic date of 31 December 2020 and volumes have been reported separately.

(iii)  Given our announcement of a binding share sale agreement for the merger of BHP's oil and gas portfolio with Woodside in November 2021, no further annual production guidance for FY22 for Petroleum will be provided. However, until merger completion, we expect a production run rate broadly consistent with the original FY22 production guidance of between 99 and 106 MMboe.

4

Summary of disclosures

BHP expects its December 2021 half year financial results to reflect certain items as summarised in the table below. The table does not provide a comprehensive list of all items impacting the period. The financial statements are the subject of ongoing work that will not be finalised until the release of the financial results on 15 February 2022. Accordingly the information in the table below contains preliminary information that is subject to update and finalisation.

Description

H1 FY22
impact
US$M(i)

Classification(ii)

Unit costs for WAIO, Escondida and NSWEC are expected to be in line with full year guidance (at guidance exchange rates), with WAIO tracking towards the bottom end of guidance

Note: weaker Australian dollar and Chilean peso than guidance rates in the period(iii)

-

 Operating costs

Unit cost guidance for Queensland Coal has been increased to between US$85 and US$94 per tonne (at guidance exchange rates), reflecting lower expected volumes for the full year

-

Operating costs

Exploration expense (minerals exploration programs)

80

Exploration expense

Higher depreciation and amortisation mainly at WAIO following South Flank commissioning and prior period update of closure provision at Yandi.

425 - 475

↑ Depreciation, amortisation

and impairments

The Group's adjusted effective tax rate for H1 FY22 is expected to be slightly below the full year guidance range of 32 to 37 per cent given Petroleum will be presented as a discontinued operation. An updated guidance range will be provided in the half year financial results

-

Taxation expense

Working capital movements relating to royalties, inventory builds, net price impacts on receivables and other movements.

2,000 - 2,500

Operating cash inflow

Dividends received from Cerrejón

~240(iv)

↑ Operating cash inflow

Dividends paid to non-controlling interests

~1,250

 Financing cash outflow

Impairment of US deferred tax assets no longer expected to be recoverable after the Petroleum merger (after tax)

400 -  450

Exceptional item charge

Financial impact on BHP Brasil of the Samarco dam failure

Refer footnote(v)

  Exceptional item charge

(i)  Numbers are not tax effected, unless otherwise noted.

(ii)  There will be a corresponding balance sheet, cash flow and/or income statement impact as relevant, unless otherwise noted.

(iii)  Average exchange rates for H1 FY22 of AUD/USD 0.73 (guidance rate AUD/USD 0.78) and USD/CLP 798 (guidance rate USD/CLP 727).

(iv)  There will be no net income statement impact in relation to Cerrejón for H1 FY22. While the dividends received will be recognised as other income, the associated adjustment to the proceeds to be received on sale completion results in an offsetting expense to reflect the reduction in the carrying value of the Cerrejón assets held for sale.

(v)  Financial impact is the subject of ongoing work and is not yet finalised. See corporate update section for further information on Samarco.

The December 2021 half year financial results are being prepared on the basis that BHP Petroleum will be reported as a discontinued operation. BHP Petroleum will be excluded from the consolidated Income Statement and will not be included when calculating the minimum dividend payout. BMC will continue to be consolidated with Queensland Coal as a continuing operation until the expected completion in the middle of the 2022 calendar year. On the Balance Sheet, both BMC and BHP Petroleum will be reclassified as assets held for sale and excluded from net operating assets.

Major development projects

At the end of December 2021, BHP had two major projects under development, the US$2.97 billion Jansen mine shafts project and the US$5.7 billion Jansen Stage 1 project.

5
 

Average realised prices

The average realised prices achieved for our major commodities are summarised below.

Average realised prices(i)

Dec H21

Dec H20

Jun H21

FY21

Dec H21
vs
Dec H20

Dec H21
vs
Jun H21

Dec H21
vs
FY21

Copper (US$/lb)

4.31

3.32

4.34

3.81

30%

(1%)

13%

Iron ore (US$/wmt, FOB)

113.54

103.78

158.17

130.56

9%

(28%)

(13%)

Metallurgical coal (US$/t)

259.71

97.61

114.81

106.64

166%

126%

144%

Hard coking coal (US$/t)(ii)

278.60

106.30

118.54

112.72

162%

135%

147%

Weak coking coal (US$/t)(ii)

218.65

73.17

104.40

89.62

199%

109%

144%

Thermal coal (US$/t)(iii)

137.68

44.35

70.83

58.42

210%

94%

136%

Nickel metal (US$/t)

19,651

15,140

17,537

16,250

30%

12%

21%

Discontinued operations

 

 

 

 

 

 

 

Oil (crude and condensate) (US$/bbl)

74.26

41.40

63.05

52.56

79%

18%

41%

Natural gas (US$/Mscf)(iv)

5.80

3.83

4.86

4.34

51%

19%

34%

LNG (US$/Mscf)

15.10

4.45

7.04

5.63

239%

114%

168%

(i)  Based on provisional, unaudited estimates. Prices exclude sales from equity accounted investments, third party product and internal sales, and represent the weighted average of various sales terms (for example: FOB, CIF and CFR), unless otherwise noted. Includes the impact of provisional pricing and finalisation adjustments.

(ii)  Hard coking coal (HCC) refers generally to those metallurgical coals with a Coke Strength after Reaction (CSR) of 35 and above, which includes coals across the spectrum from Premium Coking to Semi Hard Coking coals, while weak coking coal (WCC) refers generally to those metallurgical coals with a CSR below 35.

(iii)  Export sales only; excludes Cerrejón. Includes thermal coal sales from metallurgical coal mines.

(iv)  Includes internal sales.

The large majority of iron ore shipments were linked to index pricing for the month of shipment, with price differentials predominantly a reflection of market fundamentals and product quality. Iron ore sales were based on an average moisture rate of 7.2 per cent. The large majority of metallurgical coal and energy coal exports were linked to index pricing for the month of shipment or sold on the spot market at fixed or index-linked prices, with price differentials reflecting product quality. The majority of copper cathodes sales were linked to index pricing for quotation periods one month after the month of shipment, and three to four months after the month of shipment for copper concentrates sales with price differentials applied for location and treatment costs. The large majority of oil sales were linked to West Texas intermediate (WTI) or Brent based indices, with differentials applied for quality, locational and transportation costs.

At 31 December 2021, the Group had 333 kt of outstanding copper sales that were revalued at a weighted average price of US$4.42 per pound. The final price of these sales will be determined over the remainder of the 2022 financial year. In addition, 323 kt of copper sales from the 2021 financial year were subject to a finalisation adjustment in the current period. The provisional pricing and finalisation adjustments will increase Underlying EBITDA(5) by US$11 million in the December  2021 half year and are included in the average realised copper price in the above table.

6

Corporate update

Portfolio

In November 2021, BHP announced it had signed a Share Sale and Purchase Agreement with Stanmore Resources Limited to divest its 80 per cent interest in BHP Mitsui Coal Pty Ltd (BMC), an operated metallurgical coal joint venture in Queensland.The purchase price comprises US$1.1 billion cash on completion, US$100 million in cash six months after completion and the potential for up to US$150 million in a price-linked earn-out payable in the 2024 calendar year. Completion is expected in the middle of the 2022 calendar year subject to the satisfaction of certain conditions, including customary competition and regulatory conditions.

In November 2021, BHP signed a binding Share Sale Agreement for the merger of BHP's oil and gas portfolio with Woodside to create a global top 10 independent energy company by production. It is proposed that Woodside will acquire BHP Petroleum in exchange for new Woodside shares. Completion of the merger is subject to satisfaction of conditions precedent including regulatory and competition authority approvals and approval by Woodside's shareholders. The process remains on track and the Australian Competition and Consumer Commission provided informal clearance of the merger in December 2021. The Woodside shareholder meeting to vote on the merger as well as completion of the merger is targeted for the June 2022 quarter. In addition to its primary listing on the Australian Securities Exchange, Woodside is pursuing a standard listing on the London Stock Exchange and a listing of American Depositary Receipts on the New York Stock Exchange.

In December 2021, BHP announced a final decision to unify BHP's corporate structure under its existing Australian parent company, BHP Group Limited. The Board believes that unification is in the best interests of BHP shareholders. Unification will create a corporate structure that is simpler and more efficient, reduces duplication and streamlines BHP's governance and internal processes. Shareholder meetings of BHP Group Limited and BHP Group Plc will take place on 20 January 2022 to approve unification. Unification is expected to complete by 31 January 2022 subject to shareholder approval of both BHP Group Limited and BHP Group Plc and UK Court sanction of the scheme.

In December 2021, BHP announced it would not increase or extend its offer to acquire Noront Resources. BHP is committed to its strict capital discipline framework and while the Eagle's Nest deposit is a promising resource, we do not see adequate long-term value for BHP shareholders to support an increase in BHP's offer to match the proposal from Wyloo Metals Pty Ltd.

In December 2021, BHP advanced its early-stage nickel interests by agreeing to invest in the Kabanga Nickel Project (Kabanga), a high-quality nickel sulphide deposit in Tanzania. Kabanga is a joint venture between Kabanga Nickel Limited (84 per cent interest) and the Government of Tanzania (16 per cent). BHP has made an initial investment of US$40 million in Kabanga, which will convert into an 8.9 per cent equity stake in Kabanga Nickel Limited once approvals and conditions are met. The proceeds will be used to accelerate drilling and study work.  Further investments, including a second tranche of US$50 million, have been agreed in principle subject to the parties agreeing definitive documentation and certain other conditions. In parallel, BHP has invested US$10 million in Lifezone Limited to progress its low-carbon hydrometallurgical processing technology.

In January 2022, BHP completed the sale to Glencore of its 33.3 per cent interest in the Cerrejón joint venture in Colombia. The transaction was first announced on 29 June 2021 for a total cash consideration of US$294 million.

7

Samarco

Samarco's Judicial Reorganisation process is continuing in the Commercial Courts of Belo Horizonte, State of Minas Gerais. The Judicial Reorganisation is a process for Samarco to restructure its financial debts in order to establish a sustainable independent financial position that would allow Samarco to continue its operations safely and meet its Renova Foundation obligations. BHP Brasil will continue to support Samarco in this process.

Negotiations are ongoing with State and Federal Prosecutors and certain other Brazilian public authorities in relation to the review of the Framework Agreement. The Framework Agreement was entered into between Samarco, Vale and BHP Brasil and the relevant Brazilian authorities in March 2016 and established the Renova Foundation to develop and implement environmental and socio-economic programs to remediate and provide compensation for damage caused by the Samarco dam failure.

In October 2021, the 12th Federal Court delivered a ruling that expanded the scope of eligible individuals of the court mandated compensation process ("Novel System"), extended its geographical scope and increased indemnification amounts for certain categories of damage. The decision is under appeal and applications have been made to clarify certain aspects of the ruling. BHP is currently reviewing the impact of the 12th Federal Court's decision on the Group's provision for the Samarco dam failure and it is possible that the provision could materially increase.

In December 2021, BHP agreed to fund US$700 million in further financial support for the Renova Foundation, which will be offset against the Group's provision for the Samarco dam failure. Further funding requirements for the period to 31 December 2022 continue to be assessed and, will be subject to future approval by BHP.

We will provide an update to the ongoing potential financial impacts on BHP Brasil of the Samarco dam failure with the release of the financial results on 15 February 2022. Any financial impacts will continue to be treated as an exceptional item.

Copper

Production

 

Dec H21

Dec Q21

Dec H21
vs
Dec H20

Dec Q21
vs
Dec Q20

Dec Q21
vs
Sep Q21

Copper (kt)

 742.0

 365.5

(12%)

(15%)

(3%)

Zinc (t)

 62,892

 29,603

(18%)

(29%)

(11%)

Uranium (t)

 818

 287

(55%)

(70%)

(46%)

Copper - Total copper production decreased by 12 per cent to 742 kt. Full year production is trending towards the low end of the guidance range for the 2022 financial year, which reflects lower production guidance at Pampa Norte, and narrowed guidance ranges for Escondida and Olympic Dam. Volumes will be weighted to the second half of the financial year as expected.

Uncertainty around impacts from COVID-19 remains as the pandemic evolves, despite an improved operating environment for our Chilean assets in the December 2021 half year due to high COVID-19 vaccination rates and continued use of successful control measures at our operating sites.

8

Escondida copper production decreased by 15 per cent to 488 kt due to concentrator feed grade decline despite a record performance for material mined. Guidance for the 2022 financial year has been narrowed to between 1,020 and 1,080 kt as concentrator feed grade is expected to improve in the June 2022 half year as the mine sequence moves towards higher grade areas. Concentrator feed grade decline remains forecasted at approximately two per cent for the 2022 financial year. Medium term guidance of an annual average of 1.2 Mt of copper production over the next five years remains unchanged, with production expected to be weighted towards the latter years.

Pampa Norte copper production increased by 40 per cent to 136 kt, reflecting the continued ramp up of the Spence Growth Option (SGO), partially offset by the impact of planned lower ore stacking grade, which is expected to decline by approximately 10 per cent for the 2022 financial year. SGO demonstrated full concentrator throughput of 95 ktpd in the December 2021 quarter. Guidance for the 2022 financial year has been reduced from between 330 and 370 kt to between 260 and 300 kt, as the result of a fatality at the third party desalination plant which impacted Spence operations, operational uncertainty related to Cerro Colorado water access and licencing, including water extraction, and lower than expected recoveries at SGO. Plant design modifications, including modifications to the rougher floatation circuit will be required to increase SGO recoveries to achieve planned copper production levels. The Spence guidance to average 300 ktpa (including cathodes) in the first four years of production will be subject to the timing of these modifications being completed. 

Olympic Dam copper production decreased by 56 per cent to 44 kt as a result of the major smelter maintenance campaign in the period. The maintenance campaign was completed in January 2022 and ramp up to full capacity is now expected by April 2022 (previously March 2022), due to COVID-19 impacts on the availability of workforce. The full scope of the maintenance campaign was delivered, including the rebuild of the flash furnace and its ancillary equipment and refurbishment of the acid plant, which has resulted in significant plant improvements. Guidance for the 2022 financial year has been narrowed to between 140 and 150 kt as production is trending towards the low end of the original guidance range.

Antamina copper production increased by one per cent to 74 kt reflecting higher copper head grades and zinc production decreased by 18 per cent to 63kt reflecting lower zinc head grades. Guidance remains unchanged for the 2022 financial year, with copper production of between 120 and 140 kt, and zinc production of between 115 and 130 kt.

Iron Ore

Production

 

Dec H21

Dec Q21

Dec H21
vs
Dec H20

Dec Q21
vs
Dec Q20

Dec Q21
vs
Sep Q21

Iron ore production (kt)

 129,401

 66,102

1%

6%

4%

Iron ore - Total iron ore production increased by one per cent to 129 Mt. Guidance for the 2022 financial year remains unchanged at between 249 and 259 Mt.

9

WAIO finished the half year at near record production levels at 127 Mt (144 Mt on a 100 per cent basis), despite impacts of temporary labour constraints relating to COVID-19 border restrictions and the planned major maintenance on car dumper one and the Jimblebar train load out. This reflects continued strong supply chain performance including higher car dumper performance and improved rail cycle times. South Flank ramp up to full production capacity of 80 Mtpa (100 per cent basis) over three years remains on track with a peak rate of 45 Mtpa achieved in the half year contributing to record lump sales. In December 2021, we approved the South Flank Autonomous Haulage Project to automate the current fleet of Komatsu haul trucks. The project is scheduled to commence in the June 2022 quarter and is expected to be completed within 18 months.  The proposed easing of Western Australia's border restrictions on 5 February 2022 may introduce some short-term disruption to the operating environment as the COVID-19 pandemic evolves in the state.

Samarco production was 2.1 Mt (BHP share), following the recommencement of iron ore pellet production at one concentrator in December 2020. Guidance of between 3 and 4 Mt (BHP share) remains unchanged for the 2022 financial year.

Coal

Production

 

Dec H21

Dec Q21

Dec H21
vs
Dec H20

Dec Q21
vs
Dec Q20

Dec Q21
vs
Sep Q21

Metallurgical coal (kt)(2)

 17,668

 8,818

(8%)

(7%)

0%

Energy coal (kt)(3)

 7,205

 2,967

5%

(8%)

(30%)

Metallurgical coal - Metallurgical coal production decreased by eight per cent to 18 Mt (31 Mt on a 100 per cent basis). Guidance for the 2022 financial year has been reduced to between 38 and 41 Mt (68 and 72 Mt on a 100 per cent basis) from between 39 and 44 Mt (70 and 78 Mt on a 100 per cent basis). The revision is a result of significant La Niña related wet weather impacts during the December 2021 quarter coupled with COVID-19 related labour constraints. Workforce absenteeism arising from the COVID-19 Omicron variant is anticipated to continue into the early part of the second half of the 2022 financial year.

Queensland Coal production decreased due to significant wet weather, with double the amount of rainfall, coupled with COVID-19 related labour constraints impacting stripping and mine productivity across most operations. A longwall move was successfully executed at Broadmeadow and the Caval Ridge wash plant maintenance was also completed on time during the December 2021 quarter.

Following the recent easing of Queensland's border restrictions, COVID-19 related absenteeism has increased and remains a risk for the remainder of the year.

Energy coal - Energy coal production increased by five per cent to 7 Mt. Guidance for the 2022 financial year remains unchanged at between 13 and 15 Mt. The divestment of our interest in Cerrejón was completed in January 2022 and Cerrejón volumes are no longer included in energy coal guidance.

NSWEC production increased as a result of increased stripping volumes enabled by continued truck productivity and mining in lower strip ratio areas, despite increased rainfall and COVID-19 related impacts. High quality products now make up approximately 80 per cent of sales compared to approximately 60 per cent of sales in the prior period.

10

Other

Nickel production

 

Dec H21

Dec Q21

Dec H21
vs
Dec H20

Dec Q21
vs
Dec Q20

Dec Q21
vs
Sep Q21

Nickel (kt)

 39.3

 21.5

(15%)

(10%)

21%

Nickel - Nickel West production decreased by 15 per cent to 39 kt, reflecting planned maintenance at the Kalgoorlie Smelter, Kwinana Refinery and the Leinster and Kambalda concentrators in the September 2021 quarter, and planned asset integrity work to support operational stability completed in the December 2021 quarter. Guidance for the 2022 financial year remains unchanged at between 85 and 95 kt, with volumes weighted towards the second half of the financial year. The first batch of nickel sulphate crystals were produced in the September 2021 quarter and customer certification continues. First saleable production was achieved in the December 2021 quarter.

Potash  

Projects

Project and
ownership

 

Capital expenditure US$M
 

Initial production target date

 

Capacity
 

Progress

 

Jansen Potash
(Canada)
100%

2,972

CY27

Investment to finish the excavation and lining of the production and service shafts, and to continue the installation of essential surface infrastructure and utilities.

The project is 98% complete. Target project completion in CY22.

Jansen Stage 1
(Canada)
100%

5,723

CY27

Design, engineering and construction of an underground potash mine and surface infrastructure, with capacity to produce 4.35 Mtpa.

Approved in August 2021, project is 3% complete

Minerals exploration

Minerals exploration expenditure for the December 2021 half year was US$110 million, of which US$80 million was expensed. We have continued to add to our early stage options in future facing commodities. Greenfield minerals exploration is being undertaken on advancing copper targets in Chile, Ecuador, Mexico, Peru, Canada, Australia and the south-west United States. Nickel targets are also being advanced in Canada and Australia. Specifically in copper, we are undertaking target drilling in Chile, Ecuador and the United States while further drilling is underway in Australia.

In October 2021, BHP executed its farm-in agreement for the early-stage prospective Elliott copper project covering 7,200 km2 in the Northern Territory, Australia. Under the terms of the agreement, BHP can earn up to 75 per cent interest in Elliott by spending up to A$25 million over 10 years.

Also in October 2021, BHP exercised its option to form an exploration joint venture with Red Tiger Resources for the Intercept Hill copper project, which borders Oak Dam in South Australia. 

At Oak Dam in South Australia, BHP is continuing next stage resource definition drilling, after commencing the program in May 2021.

In December 2021, BHP advanced its early-stage nickel interests by investing in the Kabanga Nickel Project (Kabanga), a high-quality nickel sulphide deposit in Tanzania. Kabanga is a joint venture between Kabanga Nickel Limited (84 per cent interest) and the Government of Tanzania (16 per cent).

11

Discontinued operations - Petroleum

Production

 

Dec Q21
vs
Sep Q21

Crude oil, condensate and natural gas liquids (MMboe)

 25.1

 12.3

13%

15%

(3%)

Natural gas (bcf)

 168.5

 80.1

(1%)

2%

(9%)

Total petroleum production (MMboe)

 53.2

 25.7

5%

8%

(7%)

BHP announced on 22 November 2021 a binding share sale agreement for the proposed merger of BHP's oil and gas portfolio with Woodside. Completion of the merger is expected in the June 2022 quarter subject to satisfaction of conditions precedent including approval by Woodside shareholders. The effective date of the merger is 1 July 2021. The half year financial results are being prepared on the basis that BHP Petroleum is a discontinued operation.

Total petroleum production increased by 5 per cent to 53 MMboe. No further guidance for the 2022 financial year will be provided for Petroleum given the business will be presented as a discontinued operation. However, until merger completion, we expect a production run rate broadly consistent with the original 2022 financial year production guidance of between 99 and 106 MMboe.

Crude oil, condensate and natural gas liquids production increased by 13 per cent to 25 MMboe, reflecting the additional 28 percent working interest acquired in Shenzi in November 2020, increased volumes from Ruby following first production in May 2021, and lower impact from weather events in the Gulf of Mexico, partially offset by natural field decline across the portfolio.

Natural gas production decreased by one per cent to 169 bcf, reflecting decreased production at North West Shelf and natural field decline across the portfolio, partially offset by increased volumes from Ruby and higher seasonal demand for gas at Bass Strait.

Projects

Project and
ownership

Capital expenditure US$M

Initial production target date

Capacity

Progress

Mad Dog Phase 2
(US Gulf of Mexico)
23.9% (non-operator)

2,154

Mid-CY22

New floating production facility with the capacity to produce up to 140,000 gross barrels of oil equivalent per day.

On schedule and budget.
The overall project is 97% complete.

Shenzi North development
(US Gulf of Mexico)
72% (operator)

392

CY24

A two-well subsea tie-in to the Shenzi platform, with the capacity to produce up to 30,000 gross barrels of oil equivalent per day.

On schedule and budget.
The overall project is 5% complete.

Scarborough
(Western Australia)
26.5% (non-operator)

1,500

CY26

New upstream facilities designed to deliver daily gas quantities to manufacture 8 Mtpa LNG and 180 TJ/day of domestic gas.

Sanctioned in November 2021.
On schedule and budget.
The overall project is 10% complete.

On 22 November 2021, we announced the approval of US$1.5 billion in capital expenditure for development of the Scarborough upstream project located in the North Carnarvon Basin, Western Australia. The approved capital expenditure represents BHP's 26.5 per cent participating interest in Phase 1 of the upstream development. Final investment decisions have also been made by Woodside and the Scarborough Joint Venture.

In the December 2021 quarter, we completed the Ruby project in Trinidad & Tobago. The project was completed on schedule and within budget, and the Ruby field is currently producing both oil and gas.

12

The Mad Dog Phase 2 project's semi-submersible platform, Argos, was towed to final location in the US Gulf of Mexico and moored. Offshore execution of construction and commissioning is in progress. First production from Mad Dog Phase 2 is expected from mid-calendar year 2022.

In December 2021, we reached a commercial milestone with the Trion project in Mexico with the filing of a Declaration of Commerciality with the National Hydrocarbons Commission. As announced in August 2021, we have moved Trion into the Front End Engineering Design (FEED) phase and work is progressing to plan. Studies are underway, focused on completion of the engineering, commercial arrangements and execution planning required to progress readiness for a Final Investment Decision from mid-calendar year 2022.

Petroleum exploration

Exploration and appraisal wells drilled during the December 2021 quarter are summarised below.

Well

Location

Target

Formation age

BHP equity

Spud date

Water depth

Total well depth

Status

Bongos-3X

Trinidad & Tobago Block TTDAA 14

Gas

Late Miocene

70% (BHP Operator)

27 July 2021

2,114 m

5,174 m

Hydrocarbons encountered

Bongos-3X ST01

Trinidad & Tobago Block TTDAA 14

Gas

Late Miocene

70% (BHP Operator)

27 July 2021

2,114 m

5,169 m

Hydrocarbons encountered

Bongos-4

Trinidad & Tobago Block TTDAA 14

Gas

Late Miocene

70% (BHP Operator)

6 August 2021

2,177 m

5,163 m

Hydrocarbons encountered

Wasabi-1

Gulf of Mexico GC124

Oil

Early Miocene

75% (BHP Operator)

7 October 2021

764 m

2,673 m

Plugged and abandoned

Wasabi-2

Gulf of Mexico GC124

Oil

Early Miocene

75% (BHP Operator)

17 November 2021

764 m

6,895 m

Drilling ahead(i)

(i)  Well depth and status as at 31 December 2021.

In Trinidad and Tobago, the Calypso appraisal drilling programme concluded on 20 December 2021. All wells encountered hydrocarbons. Bongos-3 confirmed volumes downdip of prior penetrations and Bongos-4 established volumes in a new segment. The well results are currently under evaluation and will be incorporated into the development plan.

In the central Gulf of Mexico, the Wasabi-1 well encountered a mechanical difficulty and was plugged and abandoned on 13 November 2021. Wasabi-2 (GC124-002) was spud on 17 November 2021 and drilling operations continue.

In Barbados, a 3D seismic survey was acquired in November 2021 over a portion of the Bimshire and Carlisle Bay blocks(6). Processed data is expected to be delivered in mid-calendar year 2022.

BHP has acquired interests in offshore exploration blocks in the Red Sea in Egypt.  In December 2021, the Minister of Energy in Egypt signed the Deed of Assignment for Red Sea Block 1, finalising the assignment of a 45 per cent participating interest from Chevron to BHP. The effective date of the transfer is 12 September 2021. This follows a separate agreement with Shell in March 2021 for BHP to acquire a 30 and 25 per cent non-operated working interest in Egypt's Red Sea Blocks 3 and 4, respectively. The effective date of BHP's participation in Blocks 3 and 4 is pending final government approvals.

Petroleum exploration expenditure for the December 2021 half year was US$243 million, of which US$112 million was expensed. An approximately US$540 million exploration and appraisal program is being executed for the 2022 financial year.

13

 

 

Variance analysis relates to the relative performance of BHP and/or its operations during the December 2021 half year compared with the December 2020 half year, unless otherwise noted. Production volumes, sales volumes and capital and exploration expenditure from subsidiaries are reported on a 100 per cent basis; production and sales volumes from equity accounted investments and other operations are reported on a proportionate consolidation basis. Numbers presented may not add up precisely to the totals provided due to rounding. Copper equivalent production is based on 2021 financial year average realised prices.

 

The following footnotes apply to this Operational Review:

(1)  2022 financial year unit cost guidance: Escondida US$1.20-1.40/lb, WAIO US$17.50-18.50/t, Queensland Coal US$85-94/t and NSWEC US$62-70/t; based on exchange rates of AUD/USD 0.78 and USD/CLP 727.

(2)  We announced the divestment of our interest in BMC in November 2021, however will continue to report BMC production as part of Queensland Coal. We maintain economic and operating control of BMC until the sale has completed.

(3)  We have ceased providing Cerrejón production guidance due to the completion of the divestment of our interest. The transaction has an effective economic date of 31 December 2020 and volumes have been reported separately.

(4)  Excludes Petroleum production.

(5)  Underlying EBITDA is used to help assess current operational profitability excluding the impacts of sunk costs (i.e. depreciation from initial investment). Underlying EBITDA is earnings before net finance costs, depreciation, amortisation and impairments, taxation expense, discontinued operations and exceptional items. Underlying EBITDA includes BHP's share of profit/(loss) from investments accounted for using the equity method including net finance costs, depreciation, amortisation and impairments and taxation expense/(benefit).

(6)  Permission for survey granted by the Barbados Ministry of Energy.

The following abbreviations may have been used throughout this report: barrels (bbl); billion cubic feet (bcf); cost and freight (CFR); cost, insurance and freight (CIF); dry metric tonne unit (dmtu); free on board (FOB); grams per tonne (g/t); kilograms per tonne (kg/t); kilometre (km); metre (m); million barrels of oil equivalent (MMboe); million barrels of oil per day (MMbpd);  million cubic feet per day (MMcf/d); million tonnes (Mt); million tonnes per annum (Mtpa); ounces (oz); pounds (lb); thousand barrels of oil equivalent (Mboe); thousand barrels of oil equivalent per day (Mboe/d); thousand ounces (koz); thousand standard cubic feet (Mscf); thousand tonnes (kt); thousand tonnes per annum (ktpa); thousand tonnes per day (ktpd); tonnes (t); and wet metric tonnes (wmt).

In this release, the terms 'BHP', the 'Group', 'BHP Group', 'we', 'us', 'our' and ourselves' are used to refer to BHP Group Limited, BHP Group plc and, except where the context otherwise requires, their respective subsidiaries as defined in note 30 'Subsidiaries' in section 3.1 of BHP's 30 June 2021 Annual Report and Form 20-F. Those terms do not include non-operated assets. Notwithstanding that this release may include production, financial and other information from non-operated assets, non-operated assets are not included in the BHP Group and, as a result, statements regarding our operations, assets and values apply only to our operated assets unless stated otherwise. Our non-operated assets include Antamina, Cerrejón, Samarco, Atlantis, Mad Dog, Bass Strait and North West Shelf. BHP Group cautions against undue reliance on any forward-looking statement or guidance in this release, particularly in light of the current economic climate and significant volatility, uncertainty and disruption arising in connection with COVID-19. These forward looking statements are based on information available as at the date of this release and are not guarantees or predictions of future performance and involve known and unknown risks, uncertainties and other factors, many of which are beyond our control and which may cause actual results to differ materially from those expressed in the statements contained in this release.

14

 

 

Further information on BHP can be found at: bhp.com

Authorised for lodgement by:

Stefanie Wilkinson

Group Company Secretary

 

Media Relations

 

Email: [email protected]

 

Investor Relations

 

Email: [email protected]

 

 

 

Australia and Asia

 

Gabrielle Notley

Tel: +61 3 9609 3830  Mobile: +61 411 071 715

 

Europe, Middle East and Africa

 

Neil Burrows

Tel: +44 20 7802 7484  Mobile: +44 7786 661 683

 

Americas

 

Judy Dane

Tel: +1 713 961 8283  Mobile: +1 713 299 5342

 

Australia and Asia

 

Dinesh Bishop

Mobile: +61 407 033 909

 

Europe, Middle East and Africa

 

James Bell

Tel: +44 20 7802 7144  Mobile: +44 7961 636 432

 

Americas

 

Brian Massey

Tel: +1 713 296 7919  Mobile: +1 832 870 7677

 

 

 

BHP Group Limited ABN 49 004 028 077

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Registered Office: Level 18, 171 Collins Street

Melbourne Victoria 3000 Australia

Tel +61 1300 55 4757 Fax +61 3 9609 3015

 

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Registered Office: Nova South, 160 Victoria Street

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Tel +44 20 7802 4000 Fax +44 20 7802 4111

 

 

 

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15

NEWS RELEASE       

 

   

                 

                 

19 January 2022             

                 

                 

                 

                 

                 

BHP OPERATIONAL REVIEW
FOR THE HALF YEAR ENDED 31 DECEMBER 2021

 

 

                 

Production and sales summary (Excel version)     

                 

                 

                 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

16

Production summary

 

 

 

Quarter ended

Year to date

 

BHP interest

Dec 2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Copper(1)

 

 

 

 

 

 

 

 

Copper

 

 

 

 

 

 

 

 

Payable metal in concentrate (kt)

 

 

 

 

 

 

 

 

Escondida (2)

57.5%

236.7

202.7

195.6

194.7

196.2

390.9

473.4

Pampa Norte (3)

100.0%

0.7

5.6

21.1

26.4

24.2

50.6

0.7

Antamina

33.8%

38.6

34.7

36.1

35.8

38.4

74.2

73.2

 

 

 

 

 

 

 

 

 

Total

 

276.0

243.0

252.8

256.9

258.8

515.7

547.3

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cathode (kt)

 

 

 

 

 

 

 

 

Escondida (2)

57.5%

50.9

46.6

51.1

49.0

48.4

97.4

98.8

Pampa Norte (3)

100%

53.6

46.4

48.3

41.1

44.1

85.2

96.1

Olympic Dam

100%

47.6

55.4

50.8

29.5

14.2

43.7

99.1

 

 

 

 

 

 

 

 

 

Total

 

152.1

148.4

150.2

119.6

106.7

226.3

294.0

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total copper (kt)

 

428.1

391.4

403.0

376.5

365.5

742.0

841.3

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Lead

 

 

 

 

 

 

 

 

Payable metal in concentrate (t)

 

 

 

 

 

 

 

 

Antamina

33.8%

993

468

381

378

277

655

1,683

 

 

 

 

 

 

 

 

 

Total

 

993

468

381

378

277

655

1,683

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Zinc

 

 

 

 

 

 

 

 

Payable metal in concentrate (t)

 

 

 

 

 

 

 

 

Antamina

33.8%

41,909

33,299

35,483

33,289

29,603

62,892

76,307

 

 

 

 

 

 

 

 

 

Total

 

41,909

33,299

35,483

33,289

29,603

62,892

76,307

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Gold

 

 

 

 

 

 

 

 

Payable metal in concentrate (troy oz)

 

 

 

 

 

 

 

Escondida (2)

57.5%

47,789

37,954

38,893

41,962

42,937

84,899

90,121

Pampa Norte (3)

100%

-

-

4,728

6,967

5,776

12,743

-

Olympic Dam (refined gold)

100%

23,837

37,075

48,478

26,277

37,805

64,082

60,445

 

 

 

 

 

 

 

 

 

Total

 

71,626

75,029

92,099

75,206

86,518

161,724

150,566

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Silver

 

 

 

 

 

 

 

 

Payable metal in concentrate (troy koz)

 

 

 

 

 

 

 

Escondida (2)

57.5%

1,627

1,318

1,234

1,291

1,462

2,753

3,207

Pampa Norte (3)

100%

-

-

214

273

215

488

-

Antamina

33.8%

1,767

1,463

1,409

1,367

1,308

2,675

3,093

Olympic Dam (refined silver)

100%

193

275

185

191

258

449

350

 

 

 

 

 

 

 

 

 

Total

 

3,587

3,056

3,042

3,122

3,243

6,365

6,650

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

17

Production summary

 

 

 

Quarter ended

Year to date

 

BHP interest

Dec 2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Uranium

 

 

 

 

 

 

 

 

Payable metal in concentrate (t)

 

 

 

 

 

 

 

 

Olympic Dam

100%

945

834

614

531

287

818

1,819

 

 

 

 

 

 

 

 

 

Total

 

945

834

614

531

287

818

1,819

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Molybdenum

 

 

 

 

 

 

 

 

Payable metal in concentrate (t)

 

 

 

 

 

 

 

 

Pampa Norte (3)

100%

-

-

-

-

-

-

-

Antamina

33.8%

192

276

111

142

217

359

476

 

 

 

 

 

 

 

 

 

Total

 

192

276

111

142

217

359

476

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Iron Ore

 

 

 

 

 

 

 

 

Iron Ore

 

 

 

 

 

 

 

 

Production (kt) (4)

 

 

 

 

 

 

 

 

Newman

85%

17,637

14,614

14,560

16,461

14,577

31,038

34,047

Area C Joint Venture

85%

11,567

13,010

15,920

18,947

22,911

41,858

23,456

Yandi Joint Venture

85%

16,413

16,112

18,405

11,834

12,261

24,095

34,079

Jimblebar (5)

85%

16,740

15,241

15,337

15,009

15,324

30,333

36,815

Samarco

50%

37

878

1,023

1,048

1,029

2,077

37

 

 

 

 

 

 

 

 

 

Total

 

62,394

59,855

65,245

63,299

66,102

129,401

128,434

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Coal

 

 

 

 

 

 

 

 

Metallurgical coal

 

 

 

 

 

 

 

 

Production (kt)(6)

 

 

 

 

 

 

 

 

BMA

50%

7,539

7,727

9,253

6,715

6,300

13,015

14,904

BHP Mitsui Coal (7) (8)

80%

1,983

1,863

2,570

2,135

2,518

4,653

4,308

 

 

 

 

 

 

 

 

 

Total

 

9,522

9,590

11,823

8,850

8,818

17,668

19,212

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Energy coal

 

 

 

 

 

 

 

 

Production (kt)

 

 

 

 

 

 

 

 

NSW Energy Coal

100%

3,229

2,981

4,492

4,238

2,967

7,205

6,853

 

 

 

 

 

 

 

 

 

Total

 

3,229

2,981

4,492

4,238

2,967

7,205

6,853

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Production (kt)

 

 

 

 

 

 

 

 

Cerrejón

33.3%

347

1,795

1,784

2,060

2,176

4,236

1,385

 

 

 

 

 

 

 

 

 

Total

 

347

1,795

1,784

2,060

2,176

4,236

1,385

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other

 

 

 

 

 

 

 

 

Nickel

 

 

 

 

 

 

 

 

Saleable production (kt)

 

 

 

 

 

 

 

 

Nickel West

100%

24.0

20.4

22.4

17.8

21.5

39.3

46.2

 

 

 

 

 

 

 

 

 

Total

 

24.0

20.4

22.4

17.8

21.5

39.3

46.2

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cobalt

 

 

 

 

 

 

 

 

Saleable production (t)

 

 

 

 

 

 

 

 

Nickel West

100%

236

273

241

177

220

397

474

 

 

 

 

 

 

 

 

 

Total

 

236

273

241

177

220

397

474

 

 

 

 

 

 

 

 

 

 

 

 

18

Production summary

 

 

 

Quarter ended

Year to date

 

BHP interest

Dec 2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Discontinued operations

 

 

 

 

 

 

 

 

Petroleum (9)

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

 

Crude oil, condensate and NGL (Mboe)

 

10,729

11,601

12,205

12,751

12,345

25,096

22,236

Natural gas (bcf)

 

78.5

82.6

88.6

88.4

80.1

168.5

169.4

 

 

 

 

 

 

 

 

 

Total (Mboe)

 

23,812

25,368

26,972

27,484

25,695

53,179

50,469

 

 

 

 

 

 

 

 

 

     

 

 

 

 

 

 

 

 

 

(1)   Metal production is reported on the basis of payable metal.

(2)  Shown on a 100% basis. BHP interest in saleable production is 57.5%.

(3)  Includes Cerro Colorado and Spence.

(4)   Iron ore production is reported on a wet tonnes basis.

(5)   Shown on a 100% basis. BHP interest in saleable production is 85%.

(6)  Metallurgical coal production is reported on the basis of saleable product. Production figures include some thermal coal.

(7)  Shown on a 100% basis. BHP interest in saleable production is 80%.

(8)   We announced the divestment of our interest in BHP Mitsui Coal (BMC) in November 2021, but will continue to report BMC as part of Queensland Coal as we maintain economic and operating control of BMC until the sale has completed.

(9)   LPG and ethane are reported as natural gas liquids (NGL). Product-specific conversions are made and NGL is reported in barrels of oil equivalent (boe). Total boe conversions are based on 6 bcf of natural gas equals 1,000 Mboe.

 

Throughout this report figures in italics indicate that this figure has been adjusted since it was previously reported.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

19

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec 2020

Mar 2021

Jun 2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Copper

 

 

 

 

 

 

 

 

Metals production is payable metal unless otherwise stated.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Escondida, Chile(1)

 

 

 

 

 

 

 

 

Material mined

(kt)

97,274

95,978

104,043

113,874

117,284

231,158

180,631

Concentrator throughput

(kt)

36,303

32,654

31,903

33,528

35,787

69,315

71,036

Average copper grade - concentrator

(%)

0.83%

0.78%

0.77%

0.73%

0.71%

0.72%

0.84%

Production ex mill

(kt)

246.1

207.8

202.8

201.2

203.6

404.8

490.0

 

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

 

Payable copper

(kt)

236.7

202.7

195.6

194.7

196.2

390.9

473.4

Copper cathode (EW)

(kt)

50.9

46.6

51.1

49.0

48.4

97.4

98.8

 - Oxide leach

(kt)

18.0

16.1

14.5

14.8

13.1

27.9

33.3

 - Sulphide leach

(kt)

32.9

30.5

36.6

34.2

35.3

69.5

65.5

 

 

 

 

 

 

 

 

 

Total copper

(kt)

287.6

249.3

246.7

243.7

244.6

488.3

572.2

 

 

 

 

 

 

 

 

 

Payable gold concentrate

(troy oz)

47,789

37,954

38,893

41,962

42,937

84,899

90,121

Payable silver concentrate

(troy koz)

1,627

1,318

1,234

1,291

1,462

2,753

3,207

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Payable copper

(kt)

244.3

196.9

194.1

190.5

200.2

390.7

481.4

Copper cathode (EW)

(kt)

47.7

49.6

49.6

46.7

49.7

96.4

94.2

Payable gold concentrate

(troy oz)

47,789

37,954

38,893

41,962

42,937

84,899

90,121

Payable silver concentrate

(troy koz)

1,627

1,318

1,234

1,291

1,462

2,753

3,207

(1)  Shown on a 100% basis. BHP interest in saleable production is 57.5%.

 

 

 

 

 

 

 

 

 

 

 

 

 

20

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec 2020

Mar 2021

Jun 2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Pampa Norte, Chile

 

 

 

 

 

 

 

 

Cerro Colorado

 

 

 

 

 

 

 

 

Material mined

(kt)

6,750

6,153

5,498

5,378

4,782

10,160

19,368

Ore stacked

(kt)

3,562

3,283

3,702

3,566

4,029

7,595

7,598

Average copper grade - stacked

(%)

0.58%

0.58%

0.58%

0.60%

0.62%

0.61%

0.62%

 

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

 

Copper cathode (EW)

(kt)

15.8

13.9

14.7

13.4

15.3

28.7

31.6

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Copper cathode (EW)

(kt)

16.6

13.2

15.4

12.1

16.0

28.1

31.2

 

 

 

 

 

 

 

 

 

Spence

 

 

 

 

 

 

 

 

Material mined

(kt)

18,485

19,195

21,262

21,154

24,025

45,179

36,745

Ore stacked

(kt)

5,602

5,536

4,609

5,258

5,071

10,329

10,010

Average copper grade - stacked

(%)

0.83%

0.64%

0.72%

0.64%

0.66%

0.65%

0.95%

Concentrator throughput

(kt)

1,207

2,471

4,929

5,786

6,234

12,020

1,207

Average copper grade - concentrator

(%)

-

0.58%

0.63%

0.65%

0.60%

0.62%

-

 

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

 

Payable copper

(kt)

0.7

5.6

21.1

26.4

24.2

50.6

0.7

Copper cathode (EW)

(kt)

37.8

32.5

33.6

27.7

28.8

56.5

64.5

 

 

 

 

 

 

 

 

 

Total copper

(kt)

38.5

38.1

54.7

54.1

53.0

107.1

65.2

 

 

 

 

 

 

 

 

 

Payable gold concentrate

(troy oz)

-

-

4,728

6,967

5,776

12,743

-

Payable silver concentrate

(troy koz)

-

-

214

273

215

488

-

Payable molybdenum

(t)

-

-

-

-

-

-

-

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Payable copper

(kt)

-

1.8

20.8

28.4

24.9

53.3

-

Copper cathode (EW)

(kt)

40.9

30.7

34.1

27.7

31.2

58.9

65.0

Payable gold concentrate

(troy oz)

-

-

4,728.0

6,967.0

5,776

12,743

-

Payable silver concentrate

(troy koz)

-

-

214.0

273.0

215

488

-

Payable molybdenum

(t)

-

-

-

-

-

-

-

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

21

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec 2020

Mar 2021

Jun 2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Copper (continued)

 

 

 

 

 

 

 

 

Metals production is payable metal unless otherwise stated.

 

 

 

 

 

 

 

 

 

Antamina, Peru

 

 

 

 

 

 

 

 

Material mined (100%)

(kt)

57,029

53,762

63,393

66,581

58,179

124,760

102,487

Concentrator throughput (100%)

(kt)

14,083

12,651

13,466

13,219

13,011

26,230

27,285

Average head grades

 

 

 

 

 

 

 

 

 - Copper

(%)

0.97%

0.94%

0.93%

0.97%

1.00%

0.98%

0.96%

 - Zinc

(%)

1.30%

1.16%

1.24%

1.16%

1.11%

1.14%

1.30%

 

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

 

Payable copper

(kt)

38.6

34.7

36.1

35.8

38.4

74.2

73.2

Payable zinc

(t)

41,909

33,299

35,483

33,289

29,603

62,892

76,307

Payable silver

(troy koz)

1,767

1,463

1,409

1,367

1,308

2,675

3,093

Payable lead

(t)

993

468

381

378

277

655

1,683

Payable molybdenum

(t)

192

276

111

142

217

359

476

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Payable copper

(kt)

40.7

31.7

37.3

32.7

41.9

74.6

74.5

Payable zinc

(t)

45,109

34,141

32,044

32,635

32,513

65,148

77,878

Payable silver

(troy koz)

1,728

1,342

1,540

1,103

1,405

2,508

3,038

Payable lead

(t)

945

689

556

232

344

576

1,693

Payable molybdenum

(t)

352

192

268

86

170

256

744

 

 

 

 

 

 

 

 

 

Olympic Dam, Australia

 

 

 

 

 

 

 

 

Material mined (1)

(kt)

2,379

1,979

2,143

1,935

1,998

3,933

4,582

Ore Milled

(kt)

2,377

2,238

2,429

2,024

1,105

3,129

4,820

Average copper grade

(%)

2.01%

2.02%

1.95%

2.03%

2.17%

2.08%

2.02%

Average uranium grade

(kg/t)

0.60

0.61

0.56

0.55

0.55

0.55

0.56

 

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

 

Copper cathode (ER and EW)

(kt)

47.6

55.4

50.8

29.5

14.2

43.7

99.1

Payable uranium

(t)

945

834

614

531

287

818

1,819

Refined gold

(troy oz)

23,837

37,075

48,478

26,277

37,805

64,082

60,445

Refined silver

(troy koz)

193

275

185

191

258

449

350

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Copper cathode (ER and EW)

(kt)

46.6

55.6

52.7

29.1

17.9

47.0

96.1

Payable uranium

(t)

999

779

1,179

536

541

1,077

1,858

Refined gold

(troy oz)

21,390

38,852

47,300

24,654

38,768

63,422

57,444

Refined silver

(troy koz)

165

242

245

126

290

416

387

 

 

 

 

 

 

 

 

 

(1)  Material mined refers to underground ore mined, subsequently hoisted or trucked to surface.

 

 

 

 

 

22

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec
2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Iron Ore

 

 

 

 

 

 

 

 

Iron ore production and sales are reported on a wet tonnes basis.

 

 

 

 

 

 

 

 

 

Western Australia Iron Ore, Australia

 

 

 

 

 

 

 

 

Production

 

 

 

 

 

 

 

 

Newman

(kt)

17,637

14,614

14,560

16,461

14,577

31,038

34,047

Area C Joint Venture

(kt)

11,567

13,010

15,920

18,947

22,911

41,858

23,456

Yandi Joint Venture

(kt)

16,413

16,112

18,405

11,834

12,261

24,095

34,079

Jimblebar (1)

(kt)

16,740

15,241

15,337

15,009

15,324

30,333

36,815

Wheelarra

(kt)

-

-

-

-

-

-

-

 

 

 

 

 

 

 

 

 

Total production

(kt)

62,357

58,977

64,222

62,251

65,073

127,324

128,397

 

 

 

 

 

 

 

 

 

Total production (100%)

(kt)

70,407

66,695

72,848

70,587

73,852

144,439

144,559

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Lump

(kt)

16,703

15,593

16,410

17,546

17,827

35,373

33,759

Fines

(kt)

46,124

42,939

48,837

45,039

46,809

91,848

94,514

 

 

 

 

 

 

 

 

 

Total

(kt)

62,827

58,532

65,247

62,585

64,636

127,221

128,273

 

 

 

 

 

 

 

 

 

Total sales (100%)

(kt)

70,772

66,032

73,712

70,815

73,222

144,037

144,127

 

 

 

 

 

 

 

 

 

(1)  Shown on a 100% basis. BHP interest in saleable production is 85%.

Samarco, Brazil (1)

 

 

 

 

 

 

 

 

Production

(kt)

37

878

1,023

1,048

1,029

2,077

37

 

 

 

 

 

 

 

 

 

Sales

(kt)

-

646

1,052

1,111

950

2,061

-

 

 

 

 

 

 

 

 

 

(1)   Samarco commenced iron ore pellet production in December 2020 after meeting the licencing requirements to restart operations at the Germano complex in Minas Gerais and Ubu complex in Espírito Santo, Brazil.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

23

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec
2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Coal

 

 

 

 

 

 

 

 

Coal production is reported on the basis of saleable product.

 

 

 

 

 

 

 

 

 

Queensland Coal, Australia

 

 

 

 

 

 

 

 

Production(1)

 

 

 

 

 

 

 

 

BMA

 

 

 

 

 

 

 

 

Blackwater

(kt)

1,737

1,416

1,887

1,403

1,202

2,605

2,921

Goonyella

(kt)

2,152

2,232

2,752

1,798

1,797

3,595

4,464

Peak Downs

(kt)

1,213

1,595

1,597

1,223

960

2,183

2,700

Saraji

(kt)

1,043

1,238

1,391

999

1,081

2,080

1,860

Daunia

(kt)

464

496

478

377

304

681

954

Caval Ridge

(kt)

930

750

1,148

915

956

1,871

2,005

 

 

 

 

 

 

 

 

 

Total BMA

(kt)

7,539

7,727

9,253

6,715

6,300

13,015

14,904

 

 

 

 

 

 

 

 

 

Total BMA (100%)

(kt)

15,078

15,454

18,506

13,430

12,600

26,030

29,808

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

BHP Mitsui Coal(2) (3)

 

 

 

 

 

 

 

 

South Walker Creek

(kt)

1,118

1,031

1,500

1,462

1,535

2,997

2,356

Poitrel

(kt)

865

832

1,070

673

983

1,656

1,952

 

 

 

 

 

 

 

 

 

Total BHP Mitsui Coal

(kt)

1,983

1,863

2,570

2,135

2,518

4,653

4,308

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Queensland Coal

(kt)

9,522

9,590

11,823

8,850

8,818

17,668

19,212

 

 

 

 

 

 

 

 

 

Total Queensland Coal (100%)

(kt)

17,061

17,317

21,076

15,565

15,118

30,683

34,116

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

BMA

 

 

 

 

 

 

 

 

Coking coal

(kt)

6,531

6,752

7,801

5,415

4,875

10,290

12,718

Weak coking coal

(kt)

936

1,038

1,069

734

754

1,488

1,913

Thermal coal

(kt)

3

206

400

576

455

1,031

61

 

 

 

 

 

 

 

 

 

Total BMA

(kt)

7,470

7,996

9,270

6,725

6,084

12,809

14,692

 

 

 

 

 

 

 

 

 

Total BMA (100%)

(kt)

14,940

15,992

18,540

13,450

12,168

25,618

29,384

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

BHP Mitsui Coal(2) (3)

 

 

 

 

 

 

 

 

Coking coal

(kt)

604

357

535

313

458

771

1,275

Weak coking coal

(kt)

1,518

1,404

2,027

1,788

1,812

3,600

3,063

Thermal coal

(kt)

-

-

-

-

-

-

-

 

 

 

 

 

 

 

 

 

Total BHP Mitsui Coal

(kt)

2,122

1,761

2,562

2,101

2,270

4,371

4,338

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Queensland Coal

(kt)

9,592

9,757

11,832

8,826

8,354

17,180

19,030

 

 

 

 

 

 

 

 

 

Total Queensland Coal (100%)

(kt)

17,062

17,753

21,102

15,551

14,438

29,989

33,722

 

 

 

 

 

 

 

 

 

(1)   Production figures include some thermal coal.

(2)    Shown on a 100% basis. BHP interest in saleable production is 80%.

(3)    We announced the divestment of our interest in BHP Mitsui Coal (BMC) in November 2021, but will continue to report BMC as part of Queensland Coal as we maintain economic and operating control of BMC until the sale has completed.

 

 

24

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec
2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

NSW Energy Coal, Australia

 

 

 

 

 

 

 

 

Production

(kt)

3,229

2,981

4,492

4,238

2,967

7,205

6,853

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Sales thermal coal - export

(kt)

3,940

2,827

4,691

3,780

3,718

7,498

7,108

Inland thermal coal (1)

(kt)

-

-

-

-

-

-

-

 

 

 

 

 

 

 

 

 

Total

(kt)

3,940

2,827

4,691

3,780

3,718

7,498

7,108

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(1)   The domestic sales contract ended in the September 2019 quarter.

 

 

 

Quarter ended

Year to date

 

 

Dec
2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Cerrejón, Colombia

 

 

 

 

 

 

 

 

Production

(kt)

347

1,795

1,784

2,060

2,176

4,236

1,385

 

 

 

 

 

 

 

 

 

Sales thermal coal - export

(kt)

370

1,746

1,619

2,180

2,012

4,192

1,364

     

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other

 

 

 

 

 

 

 

 

Nickel production is reported on the basis of saleable product

 

 

 

 

 

 

 

 

 

Nickel West, Australia

 

 

 

 

 

 

 

 

Mt Keith

 

 

 

 

 

 

 

 

Nickel concentrate

(kt)

55.7

54.1

50.4

53.7

47.0

100.7

120.1

Average nickel grade

(%)

14.7

13.3

13.3

14.6

13.2

13.9

15.3

 

 

 

 

 

 

 

 

 

Leinster

 

 

 

 

 

 

 

 

Nickel concentrate

(kt)

72.8

71.5

71.4

73.8

77.4

151.2

139.0

Average nickel grade

(%)

9.5

10.2

10.5

8.9

9.1

9.0

9.3

 

 

 

 

 

 

 

 

 

Saleable production

 

 

 

 

 

 

 

 

Refined nickel (1)

(kt)

20.4

15.2

17.1

14.4

18.2

32.6

37.7

Nickel sulphate (2)

(kt)

-

-

-

-

0.4

0.4

-

Intermediates and nickel by-products (3)

(kt)

3.6

5.2

5.3

3.4

2.9

6.3

8.5

 

 

 

 

 

 

 

 

 

Total nickel

(kt)

24.0

20.4

22.4

17.8

21.5

39.3

46.2

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cobalt by-products

(t)

236

273

241

177

220

397

474

 

 

 

 

 

 

 

 

 

Sales

 

 

 

 

 

 

 

 

Refined nickel (1)

(kt)

20.9

15.0

17.8

13.8

16.9

30.7

38.0

Nickel sulphate (2)

(kt)

-

-

-

-

0.1

0.1

-

Intermediates and nickel by-products (3)

(kt)

2.6

5.9

4.0

3.9

3.1

7.0

7.2

 

 

 

 

 

 

 

 

 

Total nickel

(kt)

23.5

20.9

21.8

17.7

20.1

37.8

45.2

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cobalt by-products

(t)

237

273

241

177

220

397

475

(1)   High quality refined nickel metal, including briquettes and powder.

(2)    Nickel sulphate crystals produced from nickel powder.

(3)    Nickel contained in matte and by-product streams.

25

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec
2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Discontinued operations

 

 

 

 

 

 

 

 

Petroleum (1)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Bass Strait

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

1,003

859

1,205

1,201

971

2,172

2,308

NGL

(Mboe)

1,057

1,035

1,563

1,655

1,140

2,795

2,717

Natural gas

(bcf)

23.4

22.7

32.8

35.8

25.8

61.6

57.5

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

5,960

5,677

8,235

8,823

6,411

15,234

14,608

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

North West Shelf

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

1,180

1,183

933

973

1,027

2,000

2,395

NGL

(Mboe)

165

188

177

148

180

328

327

Natural gas

(bcf)

30.4

31.1

26.5

24.3

25.8

50.1

60.0

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

6,412

6,554

5,527

5,171

5,507

10,678

12,722

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Pyrenees

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

826

679

690

710

723

1,433

1,663

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

826

679

690

710

723

1,433

1,663

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Macedon

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

1

1

-

1

1

2

2

Natural gas

(bcf)

12.6

12.4

12.6

12.7

12.6

25.3

25.3

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

2,101

2,068

2,100

2,118

2,101

4,219

4,219

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Atlantis (2)

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

2,385

2,590

3,117

3,171

3,222

6,393

4,806

NGL

(Mboe)

147

171

218

222

186

408

301

Natural gas

(bcf)

1.1

1.4

1.6

1.7

1.5

3.2

2.3

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

2,715

2,994

3,602

3,676

3,658

7,334

5,490

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Mad Dog(2)

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

930

1,209

1,099

1,155

1,137

2,292

2,141

NGL

(Mboe)

38

57

77

46

56

102

86

Natural gas

(bcf)

0.1

0.2

0.2

0.2

0.1

0.3

0.3

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

985

1,299

1,209

1,234

1,210

2,444

2,277

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Shenzi(2) (3)

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

1,764

2,328

2,023

2,016

2,335

4,351

3,159

NGL

(Mboe)

87

130

87

102

134

236

158

Natural gas

(bcf)

0.3

0.4

0.1

0.4

0.4

0.8

0.6

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

1,901

2,525

2,127

2,185

2,536

4,721

3,417

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Trinidad/Tobago

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

96

139

236

491

396

887

198

Natural gas

(bcf)

10.5

14.4

14.7

13.3

13.9

27.2

23.3

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

1,846

2,539

2,686

2,708

2,713

5,421

4,081

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other Americas(2) (4)

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

190

187

104

83

81

164

402

NGL

(Mboe)

11

-

8

3

-

3

13

Natural gas

(bcf)

0.1

-

0.1

-

-

-

0.1

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

218

187

129

86

81

167

432

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Algeria

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

849

845

668

774

756

1,530

1,560

 

 

 

 

 

 

 

 

 

Total petroleum products

(Mboe)

849

845

668

774

756

1,530

1,560

 

 

 

 

 

 

 

 

 

26

Production and sales report

 

 

 

Quarter ended

Year to date

 

 

Dec
2020

Mar 2021

Jun
2021

Sep 2021

Dec 2021

Dec 2021

Dec 2020

Discontinued operations (continued)

 

 

 

 

 

 

 

 

Petroleum (1)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total production

 

 

 

 

 

 

 

 

Crude oil and condensate

(Mboe)

9,224

10,020

10,075

10,575

10,649

21,224

18,634

NGL

(Mboe)

1,505

1,581

2,130

2,176

1,696

3,872

3,602

Natural gas

(bcf)

78.5

82.6

88.6

88.4

80.1

168.5

169.4

 

 

 

 

 

 

 

 

 

Total

(Mboe)

23,812

25,368

26,972

27,484

25,695

53,179

50,469

 

 

 

 

 

 

 

 

 

(1)   Total boe conversions are based on 6 bcf of natural gas equals 1,000 Mboe. Negative production figures represent finalisation adjustments.

(2)    Gulf of Mexico volumes are net of royalties.

(3)   BHP completed the acquisition of an additional 28% working interest in Shenzi on 6 November 2020, taking its total working interest to 72%.

(4)   Other Americas includes Neptune, Genesis and Overriding Royalty Interest.

(5)   BHP completed the sale of its interest in the Bruce and Keith oil and gas fields on 30 November 2018. The sale has an effective date of 1 January 2018.

 

 

 

 

 

 

27

 

 

 

 

Attachment 1

Restated financial information

 

For the year ended 30 June 2021 and the half year ended 31 December 2020

 

 

28

 

Contents

 

Restated financial information                                                               Page

Basis of preparation of restated financial information                                  24

Consolidated Income Statement - Restated                                                   25

Consolidated Statement of Comprehensive Income                                       25

Consolidated Balance Sheet                                                                            26

Consolidated Cash Flow Statement - Restated                                               27

Consolidated Statement of Changes in Equity                                                 28

Restated supplementary financial information                                            29

29

 

Basis of preparation of restated financial information

This financial information for the year ended 30 June 2021 and the half year ended 31 December 2020 for the Group is not audited and has been prepared to restate previously published information for the effects of applying IFRS 5/AASB 5 'Non-current Assets Held for Sale and Discontinued Operations' to the Group's Petroleum business.

On 22 November 2021, the Group and Woodside Petroleum Ltd ('Woodside') signed a binding share sale agreement (SSA) for the merger of the Group's oil and gas portfolio with Woodside ('Merger'). The merger, which has an effective date of 1 July 2021, is subject to satisfaction of conditions precedent by 30 June 2022 or an agreed later date including shareholder, regulatory and other approvals.

Prior to completion, the Group will carry on its Petroleum business in the normal course and, while the effective date at which the right to net cash flows transferred to Woodside was 1 July 2021, the Group continues to control its Petroleum assets until the completion date of the transaction.

As such, the Group will continue to recognise its share of revenue, expenses, net finance costs and associated income tax expense related to the operation until the completion date. However, as at 31 December 2021, the Petroleum business will be classified as a disposal group held for sale and as a discontinued operation.

The nature of each change reflected in the attached restated financial information is as follows:

- All income and expense items relating to the Petroleum Discontinued Operation have been removed from the individual line items in the Consolidated Income Statement. The post-tax loss of the Petroleum Discontinued Operation is presented as a single amount in the line item titled "Loss after taxation from Discontinued operations"; and

- All cash flows and other items relating to the Petroleum Discontinued Operation have been removed from the individual line items in the Consolidated Cash Flow Statement. The net cash flows attributable to the operating, investing and financing activities of the Petroleum Discontinued Operation are each disclosed in single amounts in each section of the Consolidated Cash Flow Statement.

The Consolidated Balance Sheet, the Consolidated Statement of Comprehensive Income and the Consolidated Statement of Changes in Equity for these periods are not required to be restated. 

 

 

30

 

Consolidated Income Statement - Restated

 

 

Half year

ended

31 Dec 2020

US$M

Year

ended

30 June 2021

US$M

Continuing operations

 

 

 

Revenue

 

24,044

56,921

Other income

 

136

380

Expenses excluding net finance costs

 

(13,821)

(30,871)

Loss from equity accounted investments, related impairments and expenses

 

(470)

(915)

 

 

 

 

Profit from operations

 

9,889

25,515

 

 

 

 

 

 

 

 

Financial expenses

 

(922)

(1,290)

Financial income

 

46

67

 

 

 

 

Net finance costs

 

(876)

(1,223)

 

 

 

 

Profit before taxation

 

9,013

24,292

 

 

 

 

 

 

 

 

Income tax expense

 

(3,965)

(10,376)

Royalty-related taxation (net of income tax benefit)

 

(28)

(240)

 

 

 

 

Total taxation expense

 

(3,993)

(10,616)

 

 

 

 

Profit after taxation from Continuing operations

 

5,020

13,676

 

 

 

 

Discontinued operations

 

 

 

Loss after taxation from Discontinued operations

 

(192)

(225)

 

 

 

 

Profit after taxation from Continuing and Discontinued operations

 

4,828

13,451

 

 

 

 

Attributable to non-controlling interests

 

952

2,147

Attributable to BHP shareholders

 

3,876

11,304

 

 

 

 

 

 

 

 

Basic earnings per ordinary share (cents)

 

76.6

223.5

Diluted earnings per ordinary share (cents)

 

76.5

223.0

Basic earnings from Continuing operations per ordinary share (cents)

 

80.4

228.0

Diluted earnings from Continuing operations per ordinary share (cents)

 

80.3

227.5

 

 

 

 

 

31

 

Consolidated Statement of Comprehensive Income

 

Half year

ended

31 Dec 2020

US$M

Year

ended

30 June 2021

US$M

Profit after taxation from Continuing and Discontinued operations

4,828

13,451

Other comprehensive income

 

 

Items that may be reclassified subsequently to the income statement:

 

 

Hedges:

 

 

Gains taken to equity

1,074

863

Gains transferred to the income statement

(1,000)

(837)

Exchange fluctuations on translation of foreign operations taken to equity

5

Tax recognised within other comprehensive income

(22)

(8)

 

 

 

Total items that may be reclassified subsequently to the income statement

52

23

 

 

 

Items that will not be reclassified to the income statement:

 

 

Re-measurement (losses)/gains on pension and medical schemes

(4)

58

Equity investments held at fair value

2

(2)

Tax recognised within other comprehensive income

1

(20)

 

 

 

Total items that will not be reclassified to the income statement

(1)

36

 

 

 

Total other comprehensive income

51

59

 

 

 

Total comprehensive income

4,879

13,510

 

 

 

Attributable to non-controlling interests

953

2,158

Attributable to BHP shareholders

3,926

11,352

 

 

 

 

32

 

Consolidated Balance Sheet

 

 

ASSETS

 

Current assets

 

Cash and cash equivalents

 

Trade and other receivables

 

Other financial assets

 

Inventories

 

Assets held for sale

 

Current tax assets

 

Other

 

 

 

Total current assets

 

 

 

Non-current assets

 

Trade and other receivables

 

Other financial assets

 

Inventories

 

Property, plant and equipment

 

Intangible assets

 

Investments accounted for using the equity method

 

Deferred tax assets

 

Other

 

 

 

Total non-current assets

 

 

 

Total assets

 

 

 

LIABILITIES

 

Current liabilities

 

Trade and other payables

 

Interest bearing liabilities

 

Liabilities directly associated with the assets held for sale

 

Other financial liabilities

 

Current tax payable

 

Provisions

 

Deferred income

 

 

 

Total current liabilities

 

 

 

Non-current liabilities

 

Interest bearing liabilities

 

Other financial liabilities

 

Non-current tax payable

 

Deferred tax liabilities

 

Provisions

 

Deferred income

 

 

 

Total non-current liabilities

 

 

 

Total liabilities

 

 

 

Net assets

 

 

 

EQUITY

 

Share capital - BHP Group Limited

 

Share capital - BHP Group Plc

 

Treasury shares

 

Reserves

 

Retained earnings

 

 

 

Total equity attributable to BHP shareholders

 

Non-controlling interests

 

 

 

Total equity

 

 

 

 

33

Consolidated Cash Flow Statement - Restated

 

Half year

ended

31 Dec 2020

US$M

Year

ended

30 June 2021

US$M

Operating activities

 

 

Profit before taxation from Continuing operations

9,013

24,292

Adjustments for:

 

 

Depreciation and amortisation expense

2,405

5,084

Impairments of property, plant and equipment, financial assets and intangibles

629

2,507

Net finance costs

876

1,223

Loss from equity accounted investments, related impairments and expenses

470

915

Other

294

573

Changes in assets and liabilities:

 

 

Trade and other receivables

(1,049)

(2,389)

Inventories

(296)

(405)

Trade and other payables

45

1,149

Provisions and other assets and liabilities

(59)

486

 

 

 

Cash generated from operations

12,328

33,435

Dividends received

355

728

Interest received

60

97

Interest paid

(447)

(766)

Settlement of cash management related instruments

(202)

(401)

Net income tax and royalty-related taxation refunded

47

222

Net income tax and royalty-related taxation paid

(2,993)

(7,432)

 

 

 

Net operating cash flows from Continuing operations

9,148

25,883

 

 

 

Net operating cash flows from Discontinued operations

221

1,351

 

 

 

Net operating cash flows

9,369

27,234

 

 

 

Investing activities

 

 

Purchases of property, plant and equipment

(2,835)

(5,612)

Exploration expenditure

(86)

(192)

Exploration expenditure expensed and included in operating cash flows

56

134

Net investment and funding of equity accounted investments

(361)

(553)

Proceeds from sale of assets

86

158

Other investing

(89)

(260)

 

 

 

Net investing cash flows from Continuing operations

(3,229)

(6,325)

 

 

 

Net investing cash flows from Discontinued operations

(980)

(1,520)

 

 

 

Net investing cash flows

(4,209)

(7,845)

 

 

 

Financing activities

 

 

Proceeds from interest bearing liabilities

218

568

Proceeds from debt related instruments

90

167

Repayment of interest bearing liabilities

(6,181)

(8,357)

Purchase of shares by Employee Share Ownership Plan (ESOP) trusts

(174)

(234)

Dividends paid

(2,767)

(7,901)

Dividends paid to non-controlling interests

(762)

(2,127)

 

 

 

Net financing cash flows from Continuing operations

(9,576)

(17,884)

 

 

 

Net financing cash flows from Discontinued operations

(19)

(38)

 

 

 

Net financing cash flows

(9,595)

(17,922)

 

 

 

Net (decrease)/increase in cash and cash equivalents from Continuing operations

(3,657)

1,674

Net decrease in cash and cash equivalents from Discontinued operations

(778)

(207)

Cash and cash equivalents, net of overdrafts, at the beginning of the financial year

13,426

13,426

Foreign currency exchange rate changes on cash and cash equivalents

300

353

 

 

 

Cash and cash equivalents, net of overdrafts, at the end of period

9,291

15,246

 

 

 

 

34

Consolidated Statement of Changes in Equity for the half year ended 31 December 2020 and the year ended 30 June 2021

 

Attributable to BHP shareholders

 

 

 

Share capital

Treasury shares

 

 

 

 

 

US$M

BHP

Group

Limited

BHP

Group

Plc

BHP

Group

Limited

BHP

Group

Plc

Reserves

Retained

earnings

Total equity

attributable

to BHP

shareholders

Non- controlling interests

Total

equity

Balance as at 1 July 2020

1,111

1,057

(5)

 

2,306

43,396

47,865

4,310

52,175

 

 

 

 

 

 

 

 

 

 

Total comprehensive income

 

 

 

 

53

3,873

3,926

953

4,879

Transactions with owners:

 

 

 

 

 

 

 

 

 

Purchase of shares by ESOP Trusts

 

 

(171)

(3)

 

 

(174)

 

(174)

Employee share awards exercised net of employee contributions net of tax

 

 

147

2

(106)

(43)

 

 

 

Vested employee share awards that have lapsed, been cancelled or forfeited

 

 

 

 

(2)

2

 

 

 

Accrued employee entitlement for unexercised awards net of tax

 

 

 

 

84

 

84

 

84

Dividends

 

 

 

 

 

(2,779)

(2,779)

(762)

(3,541)

 

 

 

 

 

 

 

 

 

 

Balance as at 31 December 2020

1,111

1,057

(29)

(1)

2,335

44,449

48,922

4,501

53,423

 

 

 

 

 

 

 

 

 

 

 

 

Attributable to BHP shareholders

 

 

 

Share capital

Treasury shares

 

 

Total equity

attributable

to BHP

shareholders

Non-

controlling

interests

 

US$M

 

BHP

Group

Limited

 

BHP

Group

Plc

 

BHP

Group

Limited

 

BHP

Group

Plc

Reserves

Retained

earnings

Total

equity

Balance as at 1 July 2020

1,111

1,057

(5)

 

2,306

43,396

47,865

4,310

52,175

 

 

 

 

 

 

 

 

 

 

Total comprehensive income

 

 

 

 

22

11,330

11,352

2,158

13,510

Transactions with owners:

 

 

 

 

 

 

 

 

 

Purchase of shares by ESOP Trusts

 

 

(229)

(5)

 

 

(234)

 

(234)

Employee share awards exercised net of employee contributions net of tax

 

 

202

4

(149)

(57)

 

 

 

Vested employee share awards that have lapsed, been cancelled or forfeited

 

 

 

 

(4)

4

 

 

 

Accrued employee entitlement for unexercised awards net of tax

 

 

 

 

175

 

175

 

175

Dividends

 

 

 

 

 

(7,894)

(7,894)

(2,127)

(10,021)

 

 

 

 

 

 

 

 

 

 

Balance as at 30 June 2021

1,111

1,057

(32)

(1)

2,350

46,779

51,264

4,341

55,605

 

 

 

 

 

 

 

 

 

 

 

 

35

 
 

Restated supplementary financial information

For the half year ended 31 December 2020 and financial year ended 30 June 2021

The following pages present the supplementary financial information for the Group for the half year ended 31 December 2020 and the financial year ended 30 June 2021, restated for the effect of the application of IFRS 5/AASB 5 'Non-current Assets Held for Sale and Discontinued Operations'.

As a consequence of this accounting treatment, the Group's Petroleum business no longer meets the reporting segment recognition criteria as outlined in IFRS 8/AASB 8 'Operating segments' and therefore does not form part of the Group's reportable segments as summarised below. Petroleum underlying EBITDA, revenue, net operating assets and capital and exploration expenditure do not form part of the comparative restated reportable segment(1).

Segment summary(2)

A summary of performance for the 31 December 2020 half year and 30 June 2021 financial year is presented below and excludes Petroleum discontinued operations.

Half year ended

31 Dec  2020

US$M

Revenue(3)

Underlying EBITDA

Underlying EBIT

Exceptional Items(4)

Net operating assets

Capital expenditure

Exploration gross(5)

Exploration to profit(6)

Copper

7,067

3,738

2,899

(38)

26,623

1,108

18

18

Iron Ore

14,058

10,244

9,320

(500)

19,026

1,101

49

26

Coal

2,170

(201)

(601)

(959)

8,792

320

11

4

Group and unallocated items(7)

749

106

(218)

(14)

3,892

306

8

8

 

 

 

 

 

 

 

 

 

Total Group

24,044

13,887

11,400

(1,511)

58,333

2,835

86

56

 

 

 

 

 

 

 

 

 

 

Year ended

30 June  2021

US$M

Revenue(3)

Underlying EBITDA

Underlying EBIT

Exceptional Items(4)

Net operating assets

Capital expenditure

Exploration gross(5)

Exploration to profit(6)

Copper

15,726

8,489

6,809

(144)

26,928

2,180

53

53

Iron Ore

34,475

26,278

24,294

(1,319)

18,663

2,188

100

55

Coal

5,154

288

(577)

(1,567)

7,512

579

20

7

Group and unallocated items(7)

1,566

18

(673)

(1,308)

2,921

665

19

19

 

 

 

 

 

 

 

 

 

Total Group

56,921

35,073

29,853

(4,338)

56,024

5,612

192

134

 

 

 

 

 

 

 

 

 

 

(1)  As a result of the above mentioned planned Merger transaction with Woodside, the Group's Petroleum business does not form part of the reportable segments summarised above. Restated Petroleum financial information has been included below to reflect the performance of the Group's Petroleum discontinued operations business. 

Petroleum - Discontinued operations

US$M

Revenue

Underlying

EBITDA

D&A

Underlying EBIT

Net

operating

assets

Capital

expenditure

Exploration

gross

Exploration

to profit

Half year ended 31 December 2020

1,595

793

901

(108)

8,548

498

195

242

Year ended 30 June 2021

3,896

2,306

1,868

438

8,073

994

322

382

 

 

 

 

 

 

 

 

 

 

(2)  Group and segment level information is reported on a statutory basis which reflects the application of the equity accounting method in preparing the Group financial statements - in accordance with IFRS. Underlying EBITDA of the Group and the reportable segments, includes depreciation, amortisation and impairments (D&A), net finance costs and taxation expense of US$259 million for H1 FY21 and US$626 million for FY21 related to equity accounted investments. It excludes exceptional items loss of US$678 million for H1 FY21 and US$1,456 million for FY21 related to share of profit/loss from equity accounted investments, related impairments and expenses.

Group profit before taxation comprised Underlying EBITDA, exceptional items, depreciation, amortisation and impairments of US$3,998 million for H1 FY21 and US$9,558 million for FY21 and net finance costs of US$876 million for H1 FY21 and US$1,223 million for FY21.

36

 

 

(3)  Revenue is based on Group realised prices and includes third party products. Sale of third party products by the Group contributed revenue of US$958 million and Underlying EBITDA of US$58 million for H1 FY21 and revenue of US$2,285 million and and Underlying EBITDA of US$65 million for FY21.

(4)  Exceptional items loss of US$1,511 million H1 FY21 (FY21: US$4,338 million) excludes net finance costs of US$41 million H1 FY21 (FY21: US$85 million) included in the total loss before taxation of US$358 million H1 FY21 (US$1,087 million FY21) related to the Samarco dam failure. Refer to Exceptional items and Significant events - Samarco dam failure notes to the financial statements evident in the respective published 2021 annual report and FY21 half year reports for further information.

(5)  Includes US$30 million capitalised exploration H1 FY21 (FY21: US$58 million).

(6)  Includes US$ nil of exploration expenditure previously capitalised, written off as impaired (included in depreciation and amortisation) H1 FY21 (FY21: US$ nil).

(7)  Group and unallocated items includes functions, other unallocated operations including Potash, Nickel West, legacy assets, and consolidation adjustments. Revenue not attributable to reportable segments comprises the sale of freight and fuel to third parties, as well as revenues from unallocated operations. Exploration and technology activities are recognised within relevant segments.

Restated financial information for Petroleum Discontinued operations for the 31 December 2020 half year and the 30 June 2021 financial year, is presented below.

Half year ended

31 Dec 2020

US$M

Revenue(1)

Underlying EBITDA

D&A

Underlying EBIT

Net operating assets

Capital expenditure

Exploration gross(2)

Exploration to profit(3)

Australia Production Unit(4)

123

80

95

(15)

176

14

 

 

Bass Strait

478

319

396

(77)

1,407

33

 

 

North West Shelf

402

311

120

191

1,224

47

 

 

Atlantis

212

127

71

56

1,131

125

 

 

Shenzi

137

89

59

30

1,005

10

 

 

Mad Dog

88

61

26

35

1,774

164

 

 

Trinidad/Tobago

68

40

19

21

439

70

 

 

Algeria

75

54

54

95

1

 

 

Exploration

(181)

80

(261)

1,122

1

 

 

Other(5)

39

(105)

37

(142)

175

33

 

 

 

 

 

 

 

 

 

 

 

Total Petroleum from Group production

1,622

795

903

(108)

8,548

498

 

 

 

 

 

 

 

 

 

 

 

Third party products

3

 

 

 

 

 

 

 

 

 

 

 

Total Petroleum

1,625

795

903

(108)

8,548

498

195

242

 

 

 

 

 

 

 

 

 

Adjustment for equity accounted investments(6)

(6)

(2)

(2)

 

 

 

 

 

 

 

 

 

Total Petroleum statutory result

1,619

793

901

(108)

8,548

498

195

242

 

 

 

 

 

 

 

 

 

Inter-segment adjustments

(24)

 

 

 

 

 

 

 

 

 

Total Discontinued Operations - Petroleum

1,595

793

901

(108)

8,548

498

195

242

 

 

 

 

 

 

 

 

 

37

 

Year ended

30 June 2021

US$M

Revenue(1)

Underlying EBITDA

D&A

Underlying EBIT

Net operating assets

Capital expenditure

Exploration gross(2)

Exploration to profit(3)

Australia Production Unit(4)

327

202

186

16

64

23

 

 

Bass Strait

1,066

798

775

23

1,136

70

 

 

North West Shelf

893

761

239

522

1,281

104

 

 

Atlantis

560

401

162

239

1,109

178

 

 

Shenzi

417

309

175

134

970

113

 

 

Mad Dog

231

174

54

120

1,885

308

 

 

Trinidad/Tobago

204

80

44

36

433

152

 

 

Algeria

164

135

135

107

2

 

 

Exploration

(296)

122

(418)

1,148

 

 

Other(5)

85

(256)

114

(370)

(60)

44

 

 

 

 

 

 

 

 

 

 

 

Total Petroleum from Group production

3,947

2,308

1,871

437

8,073

994

 

 

 

 

 

 

 

 

 

 

 

Third party products

11

1

1

 

 

 

 

 

 

 

 

 

 

 

Total Petroleum

3,958

2,309

1,871

438

8,073

994

322

382

 

 

 

 

 

 

 

 

 

Adjustment for equity accounted investments(6)

(12)

(3)

(3)

 

 

 

 

 

 

 

 

 

Total Petroleum statutory result

3,946

2,306

1,868

438

8,073

994

322

382

 

 

 

 

 

 

 

 

 

Inter-segment adjustments

(50)

 

 

 

 

 

 

 

 

 

Total Discontinued Operations - Petroleum

3,896

2,306

1,868

438

8,073

994

322

382

 

 

 

 

 

 

 

 

 

· Petroleum revenue includes: crude oil US$769 million H1 FY21 (FY21: US$2,013 million), natural gas US$434 million H1 FY21 (FY21: US$977 million), LNG US$292 million (FY21: US$682 million), NGL US$96 million (FY21: US$212 million) and other (including Inter-segment adjustments) US$4 million (FY21: US$12 million).

· Includes US$14 million of capitalised exploration H1 FY21 (FY21: US$26 million).

· Includes US$61 million of exploration expenditure previously capitalised, written off as impaired (included in depreciation and amortisation) H1 FY21 (FY21: US$86 million).

· Australia Production Unit includes Macedon and Pyrenees.

· Predominantly divisional activities, business development and Neptune (sale finalised in May 2021). Also includes the Caesar oil pipeline and the Cleopatra gas pipeline, which are equity accounted investments. The financial information for the Caesar oil pipeline and the Cleopatra gas pipeline presented above, with the exception of net operating assets, reflects BHP's share.

· Total Petroleum statutory result revenue excludes US$6 million H1 FY21 (FY21: US$12 million) revenue related to the Caesar oil pipeline and the Cleopatra gas pipeline. Total Petroleum statutory result Underlying EBITDA includes US$2 million H1 FY21 (FY21: US$3 million) D&A related to the Caesar oil pipeline and the Cleopatra gas pipeline.

 

38

 

 

Alternative Performance Measures

We use various Alternative Performance Measures (APMs) to reflect our underlying financial performance.

These APMs are not defined or specified under the requirements of IFRS, but are derived from the Group's restated Financial Statements for the half year ended 31 December 2020 and year ended 30 June 2021 prepared in accordance with IFRS. The APMs and below reconciliations included in this document for the restated half year ended 31 December 2020 and year ended 30 June 2021 periods are unaudited. The APMs are consistent with how management review financial performance of the Group with the Board and the investment community.

The definitions and calculation methodology to compute the Group's APMs have not changed as a result of the proposed Merger. For further information and a list of the "Definition and calculation of alternative performance measures" refer to the Group's 2021 published Annual report.

Comparative periods have been adjusted for the effects of applying IFRS 5/AASB 5 'Non-current Assets Held for Sale and Discontinued Operations'.

The following tables provide reconciliations between the APMs and their nearest respective IFRS measure. As the Group's balance sheet is not required to be restated under IFRS 5/AASB 5 'Non-current Assets Held for Sale and Discontinued Operations', certain APMs such as Net Debt Waterfall, Net debt and gearing ratio and Underlying ROCE have not been restated and are presented consistently as previously published in respective comparable period financial information. 

Exceptional items

To improve the comparability of underlying financial performance between reporting periods some of our APMs adjust the relevant IFRS measures for exceptional items.

39

 

Exceptional items are those gains or losses where their nature, including the expected frequency of the events giving rise to them, and impact is considered material to the Group's Financial Statements. The exceptional items included within the Group's profit for each restated comparative period are detailed below.

Exceptional items

Half year ended

31 Dec 2020

US$M

Restated

Year

ended

30 June 2021

US$M

Restated

Continuing operations

 

 

Revenue

Other income

34

Expenses excluding net finance costs, depreciation, amortisation and impairments

(286)

(545)

Depreciation and amortisation

Net impairments

(547)

(2,371)

Loss from equity accounted investments, related impairments and expenses

(678)

(1,456)

 

 

 

Profit/(loss) from operations

(1,511)

(4,338)

 

 

 

 

 

 

Financial expenses

(41)

(85)

Financial income

 

 

 

Net finance costs

(41)

(85)

 

 

 

Profit/(loss) before taxation

(1,552)

(4,423)

 

 

 

 

 

 

Income tax (expense)/benefit

(590)

(1,057)

Royalty-related taxation (net of income tax benefit)

 

 

 

Total taxation (expense)/benefit

(590)

(1,057)

 

 

 

Profit/(loss) after taxation from Continuing operations

(2,142)

(5,480)

 

 

 

Discontinued operations

 

 

Profit/(loss) after taxation from Discontinued operations

(28)

(317)

 

 

 

Profit/(loss) after taxation from Continuing and Discontinued operations

(2,170)

(5,797)

 

 

 

Total exceptional items attributable to non-controlling interests

(10)

(24)

Total exceptional items attributable to BHP shareholders

(2,160)

(5,773)

 

 

 

 

 

 

Exceptional items attributable to BHP shareholders per share (US cents)

(42.8)

(114.2)

 

 

 

Weighted basic average number of shares (Million)

5,057

5,057

 

 

 

 

APMs derived from Consolidated Income Statement

Underlying attributable profit - Continuing operations

Underlying attributable profit - Continuing operations

Half year ended

31 Dec 2020

US$M

Restated

Year

ended

30 June 2021

US$M

Restated

Profit after taxation from Continuing and Discontinued operations attributable to BHP shareholders

3,876

11,304

Loss after taxation from Discontinued operations attributable to BHP shareholders

192

225

Total exceptional items attributable to BHP shareholders

2,160

5,773

Total exceptional items attributable to BHP shareholders for Discontinued operations

(28)

(317)

 

 

 

Underlying attributable profit - Continuing operations

6,200

16,985

 

 

 

 

40

 

Underlying basic earnings per share - Continuing operations

Underlying basic earnings per share - Continuing operations

Half year ended

31 Dec 2020

US$M

Restated

Year

ended

30 June 2021

US$M

Restated

Underlying attributable profit - Continuing operations

6,200

16,985

Weighted basic average number of shares (Million)

5,057

5,057

 

 

 

Underlying attributable earnings per ordinary share - Continuing operations (US cents)

122.6

335.9

 

 

 

 

Underlying EBITDA

Underlying EBITDA

Half year ended

31 Dec 2020

US$M

Restated

Year

ended

30 June 2021

US$M

Restated

Profit from operations

9,889

25,515

Exceptional items included in profit from operations

1,511

4,338

 

 

 

Underlying EBIT

11,400

29,853

 

 

 

Depreciation and amortisation expense

2,405

5,084

Net impairments

629

2,507

Exceptional item included in Depreciation, amortisation and impairments

(547)

(2,371)

 

 

 

Underlying EBITDA

13,887

35,073

 

 

 

 

Underlying EBITDA margin

Half year ended 31 Dec 2020

US$M

Restated

Copper

Iron Ore

Coal

Group and unallocated items/

eliminations(1)

Total Group

Revenue - Group production

6,129

14,050

2,170

737

23,086

Revenue - Third party products

938

8

 

12

958

 

 

 

 

 

 

Revenue

7,067

14,058

2,170

749

24,044

 

 

 

 

 

 

Underlying EBITDA - Group production

3,683

10,241

(201)

106

13,829

Underlying EBITDA - Third party products

55

3

 

 

58

 

 

 

 

 

 

Underlying EBITDA

3,738

10,244

(201)

106

13,887

 

 

 

 

 

 

Segment contribution to the Group's Underlying EBITDA(2)

27%

74%

(1%)

 

100%

Underlying EBITDA margin(3)

60%

73%

(9%)

 

60%

 

41

 

Year ended 30 June 2021

US$M

Restated

Copper

Iron Ore

Coal

Group and unallocated items/

eliminations(1)

Total Group

Revenue - Group production

13,482

34,457

5,154

1,543

54,636

Revenue - Third party products

2,244

18

23

2,285

 

 

 

 

 

 

Revenue

15,726

34,475

5,154

1,566

56,921

 

 

 

 

 

 

Underlying EBITDA - Group production

8,425

26,277

288

18

35,008

Underlying EBITDA - Third party products

64

1

65

 

 

 

 

 

 

Underlying EBITDA

8,489

26,278

288

18

35,073

 

 

 

 

 

 

Segment contribution to the Group's Underlying EBITDA(2)

24%

75%

1%

 

100%

Underlying EBITDA margin(3)

62%

76%

6%

 

64%

 

 

 

 

 

 

(1)  Group and unallocated items includes functions, other unallocated operations including Potash, Nickel West, legacy assets and consolidation adjustments.

(2)  Percentage contribution to Group Underlying EBITDA, excluding Group and unallocated items.

(3)  Underlying EBITDA margin excludes Third party products.

 

APMs derived from Consolidated Cash Flow Statement

Capital and exploration expenditure

Capital and exploration expenditure

Half year ended

31 Dec 2020

US$M

Restated

Year

ended

30 June 2021

US$M

Restated

Capital expenditure (purchases of property, plant and equipment)

2,835

5,612

Add: Exploration expenditure

86

192

 

 

 

Capital and exploration expenditure (cash basis) - Continuing operations

2,921

5,804

 

 

 

Capital and exploration expenditure - Discontinued operations

693

1,316

 

 

 

Capital and exploration expenditure (cash basis) - Total operations

3,614

7,120

 

 

 

 

Free cash flow

Free cash flow

Half year ended

31 Dec 2020

US$M

Restated

Year

ended

30 June 2021

US$M

Restated

Net operating cash flows from Continuing operations

9,148

25,883

Net investing cash flows from Continuing operations

(3,229)

(6,325)

 

 

 

Free cash flow - Continuing operations

5,919

19,558

 

 

 

Free cash flow - Discontinued operations

(759)

(169)

 

 

 

Free cash flow - Total operations

5,160

19,389

 

 

 

 

42

 

 

APMs derived from Consolidated Balance Sheet

The Group's balance sheet is not required to be restated under IFRS 5, however Net operating assets presented below, has been restated to reflect the exclusion of Petroleum from the Group's reportable segments which is to be recognised as held for sale as at 31 December 2021. 

Net operating assets

 

Half year ended

31 Dec 2020

US$M

Restated

Year

ended

30 June 2021

US$M

Restated

Net assets

53,423

55,605

 

 

 

Less: Non-operating assets

 

 

Cash and cash equivalents

(9,291)

(15,246)

Trade and other receivables(1)

(202)

(280)

Other financial assets(2)

(2,225)

(1,516)

Current tax assets

(295)

(279)

Deferred tax assets

(3,178)

(1,912)

Assets held for sale

(324)

Petroleum discontinued operations operating assets(3)

(13,745)

(13,757)

 

 

 

Add: Non-operating liabilities

 

 

Trade and other payables(4)

218

227

Interest bearing liabilities

22,719

20,983

Other financial liabilities(5)

752

588

Current tax payable

1,184

2,800

Non-current tax payable

173

120

Deferred tax liabilities

3,603

3,314

Liabilities directly associated with the assets held for sale

17

Petroleum discontinued operations operating liabilities(3)

5,197

5,684

 

 

 

Net operating assets

58,333

56,024

 

 

 

(1)  Represents loans to associates, external finance receivable and accrued interest receivable included within other receivables.

(2)  Represents cross currency and interest rate swaps, forward exchange contracts related to cash management and investment in shares and other investments.

(3)  Represents the Petroleum operating assets and operating liabilities as at 31 December 2020 and 30 June 2021 that are to be recognised as held for sale as at 31 December 2021 under IFRS 5.

(4)  Represents accrued interest payable included within other payables.

(5)  Represents cross currency and interest rate swaps and forward exchange contracts related to cash management.

 

 

43

 

 

Other APMs

The definition and calculation methodology to compute the Group's underlying ROCE calculation below, has not changed as a result of the discontinued operations impacts connected with the planned Petroleum Merger. As per our definitions, the Group's underlying ROCE includes the contribution from Discontinued operations.

However, Underlying ROCE by segment and Underlying ROCE by assets presented below, have been restated to reflect the portion attributable to the Group's Petroleum Discontinued operations and the Group's continued operations.

For further information and a list of the "Definition and calculation of alternative performance measures" refer to the Group's 2021 published Annual report.

Underlying return on capital employed (ROCE) by segment

 

 

 

 

 

 

 

 

Half year ended 31 Dec 2020

US$M

Restated

Copper

Iron Ore

Coal

Group and unallocated items/ eliminations(1)

Total

Continuing

Petroleum Discontinued operation

Total Group

Annualised profit after taxation excluding net finance costs and exceptional items

3,918

12,454

(1,066)

256

15,562

(260)

15,302

Average capital employed

23,941

16,367

8,743

5,877

54,928

9,813

64,741

 

 

 

 

 

 

 

 

Underlying Return on Capital Employed

16%

76%

(12%)

28.3%

(2.6%)

23.6%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year ended 30 June 2021

US$M

Restated

Copper

Iron Ore

Coal

Group and unallocated items/ eliminations(1)

Total

Continuing

Petroleum Discontinued operation

Total Group

Profit after taxation excluding net finance costs and exceptional items

4,191

16,640

(454)

(395)

19,982

149

20,131

Average capital employed

23,710

16,042

8,262

4,470

52,484

9,489

61,973

 

 

 

 

 

 

 

 

Underlying Return on Capital Employed

18%

104%

(5%)

38.1%

1.6%

32.5%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(1)  Group and unallocated items includes functions, other unallocated operations including Potash, Nickel West, legacy assets and consolidation adjustments. 

 

 

44

 

 

Underlying return on capital employed (ROCE) by asset

Half year ended 31 Dec 2020

US$M

Restated

Western Australia Iron Ore

Antamina

Escondida

Pampa Norte

Potash

Olympic Dam

Queensland Coal

Cerrejόn

New South Wales Energy Coal

Other

Total

Continuing

Petroleum Discontinued operation(1)

Total Group

Annualised profit after taxation excluding net finance costs and exceptional items

12,458

522

3,292

172

78

78

(330)

(58)

(482)

(168)

15,562

(260)

15,302

Average capital employed

18,614

1,364

10,593

3,752

4,468

8,028

7,622

519

557

(589)

54,928

9,813

64,741

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Underlying Return on Capital Employed

67%

38%

31%

5%

2%

1%

(4%)

(11%)

(87%)

28.3%

(2.6%)

23.6%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Year ended 30 June 2021

US$M

Restated

Western Australia Iron Ore

Antamina

Escondida

Pampa Norte

Potash

Olympic Dam

Queensland Coal

Cerrejόn

New South Wales Energy Coal

Other

Total

Continuing

Petroleum Discontinued operation(1)

Total Group

Profit after taxation excluding net finance costs and exceptional items

16,665

593

3,281

302

5

214

(103)

(13)

(203)

(759)

19,982

149

20,131

Average capital employed

18,661

1,353

10,353

3,760

3,710

8,021

7,475

483

269

(1,601)

52,484

9,489

61,973

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Underlying Return on Capital Employed

89%

44%

32%

8%

0%

3%

(1%)

(3%)

(75%)

38.1%

1.6%

32.5%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(1)  Includes exploration expenditure previously classified in Group and unallocated.

 

 

45

 

 

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