Edgar Filing: BHP BILLITON LTD

BHP Billiton Limited and BHP Billiton Plc

Date: July 19, 2017

/s/ Rachel Agnew

Rachel Agnew

Company Secretary

Form 6-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 6-K

REPORT OF FOREIGN PRIVATE ISSUER

PURSUANT TO RULE 13a-16 OR 15d-16

UNDER THE SECURITIES EXCHANGE ACT OF 1934

July 19, 2017


BHP BILLITON LIMITED (ABN 49 004 028 077) (Exact name of Registrant as specified in its charter) VICTORIA, AUSTRALIA (Jurisdiction of incorporation or organisation) 171 COLLINS STREET, MELBOURNE, VICTORIA 3000 AUSTRALIA (Address of principal executive offices)		BHP BILLITON PLC (REG. NO. 3196209) (Exact name of Registrant as specified in its charter) ENGLAND AND WALES (Jurisdiction of incorporation or organisation) NOVA SOUTH, 160 VICTORIA STREET LONDON, SW1E 5LB UNITED KINGDOM (Address of principal executive offices)

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F: ☒ Form 20-F ☐ Form 40-F

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1): ☐

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7): ☐

Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934: ☐ Yes ☒ No

If “Yes” is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b): n/a


NEWS RELEASE



Release Time		IMMEDIATE

Date		19 July 2017

Release Number		19/17

BHP OPERATIONAL REVIEW FOR THE YEAR ENDED 30 JUNE 2017

•

Achieved full year production guidance for petroleum and iron ore, with annual production records at Western Australia Iron Ore (WAIO), Spence and two Queensland Coal mines.

•

Lower copper production reflected the impact of industrial action at Escondida and the power outage and unplanned maintenance at Olympic Dam. Lower metallurgical coal volumes as a result of damage to third party rail infrastructure caused by Cyclone Debbie.

•

We expect to achieve full year unit cost guidance at WAIO and Conventional petroleum, however industrial action and Cyclone Debbie have impacted unit costs at Escondida and Queensland Coal respectively.

•

Group copper equivalent production expected to increase by 7% in the 2018 financial year.

•

In Onshore US, development activity is increasing with up to 10 rigs operating in the 2018 financial year.

•

Divestment of non-core Onshore US acreage is progressing, with the sale of a portion of the southern Hawkville anticipated in the September 2017 quarter.

•

In Petroleum exploration, drilling of the Wildling-2 appraisal well in the Gulf of Mexico is continuing, with results expected in the September 2017 quarter.

•

All major projects under development are tracking to plan.


Production	FY17		vs FY16
Petroleum (MMboe)		208		(13	%)	Deferral of development activity in Onshore US for value and natural field decline in Conventional assets.
Copper (kt)		1,326		(16	%)	Reduced volumes following industrial action at Escondida and the power outage and unplanned maintenance at Olympic Dam.
Iron ore⁽¹⁾ (Mt)		231		4	%	Record WAIO volumes reflects productivity improvements across the supply chain and additional capacity at Jimblebar.
Metallurgical coal⁽¹⁾ (Mt)		40		(6	%)	Record volumes at two Queensland Coal mines more than offset by the impacts from Cyclone Debbie.
Energy coal⁽¹⁾ (Mt)		29		7	%	Strong performance at both NSWEC and Cerrejón.

BHP Chief Executive Officer, Andrew Mackenzie said: “Our people have stepped up to unlock low-cost latent capacity and achieve strong productivity gains across our tier one assets.

Improved productivity led to record annual production at Western Australia Iron Ore, Spence and two Queensland Coal mines while production guidance was achieved by Petroleum and Western Australia Iron Ore. Copper production is expected to rebound strongly in the 2018 financial year with the commissioning of the Escondida Water Supply project and ramp-up of the Los Colorados Extension project during the September 2017 quarter to enable utilisation of Escondida’s three concentrators.

In Petroleum, the recently approved Mad Dog phase 2 project will extend low-risk oil volumes as supply tightens while in the near-term, Onshore US development activity is to increase with up to 10 rigs planned for the 2018 financial year.

Our relentless focus on safety, productivity and capital discipline will support strong growth in shareholder value.”


		1

Summary

Operational performance

Production for the 2017 financial year and guidance for the 2018 financial year are summarised in the table below.


Production	FY17		Jun 2017 Qtr		FY17 vs FY16			Jun Q17 vs Jun Q16			Jun Q17 vs Mar Q17			FY18 guidance			FY18e vs FY17
Petroleum (MMboe)		208		52		(13	%)		(7	%)		3	%		180 -190			(9%) - (13	%)
Onshore US (MMboe)		80		20		(26	%)		(15	%)		(4	%)		61 - 67			(16%) - (24	%)
Conventional (MMboe)		128		32		(2	%)		(2	%)		7	%		119 -123			(4%) -(7	%)
Copper (kt)		1,326		387		(16	%)		(6	%)		71	%		1,655 -1,790			25% - 35	%
Escondida (kt)		772		225		(21	%)		(16	%)		138	%		1,130 -1,230			46% - 59	%
Other copper⁽ⁱ⁾ (kt)		554		162		(8	%)		12	%		23	%		525 -560			(5%) - 1	%
Iron ore⁽ⁱⁱ⁾ (Mt)		231		60		4	%		8	%		12	%		239 -243			3% - 5	%
WAIO (100% basis) (Mt)		268		70		4	%		8	%		12	%		275 -280	⁽ⁱⁱⁱ⁾		3% - 4	%
Metallurgical coal⁽ⁱⁱ⁾ (Mt)		40		8		(6	%)		(27	%)		(16	%)		44 - 46			10% - 15	%
Energy coal⁽ⁱⁱ⁾ (Mt)		29		8		7	%		30	%		10	%		29 - 30			0% - 3	%

(i)	Other copper comprises Pampa Norte, Olympic Dam and Antamina.

(ii)	Excludes production from Samarco, Haju (IndoMet Coal) and New Mexico Coal.

(iii)

Subject to regulatory approvals to increase capacity above 270 Mt.

Major development projects

During the year, the Bass Strait Longford Gas Conditioning Plant was fully commissioned and is running at design capacity, enabling full production from the Turrum and Kipper fields. The BHP Board also approved the Mad Dog Phase 2 project in the deepwater Gulf of Mexico. The Escondida Water Supply project achieved mechanical completion in the December 2016 quarter and was transitioned to operations effective 1 July 2017, following completion of project commissioning in June 2017.

At the end of the 2017 financial year, BHP had three major projects under development in Petroleum and Potash, with a combined budget of US$5.1 billion over the life of the projects.

Corporate update

BHP expects to record exceptional items of US$546 million (US$740 million post-tax) in the second half of the 2017 financial year. These items relate to idle capacity and other strike-related costs incurred as a result of the Escondida industrial action in the March 2017 quarter and Chilean withholding tax on a one-off dividend paid while a concessional tax rate was available.


Exceptional items to be recognised in the June 2017 half year Charges/(credits) (US$ million)	Loss before taxation		Taxation			Loss after taxation
Escondida industrial action costs		546		(179	)		367
Withholding tax on Chilean dividends		—		373			373

On 18 January 2017, Samarco and its shareholders, Vale S.A. and BHP Billiton Brasil, entered into a preliminary agreement with the Federal Prosecutors’ Office in Brazil in relation to the Samarco dam failure (Preliminary Agreement). The Preliminary Agreement outlines the process and timeline for negotiation of a settlement of the BRL 155 billion (approximately US$47.5 billion) and BRL 20 billion (approximately US$6.1 billion) Public Civil Claims relating to the dam failure. The Court has extended the final date for negotiation of a settlement until 30 October 2017, allowing for the continuation of the interim security arrangements provided to the Court on 24 January 2017 and the provision of ongoing expert advice to the Federal Prosecutors in respect of the remediation and compensation programs identified under the Framework Agreement.


BHP Operational Review for the year ended 30 June 2017		2

On 30 June 2017, BHP announced a total of US$250 million in financial support for the Renova Foundation and Samarco until 31 December 2017. The amount of US$174 million will be used to fund the Renova Foundation and will be offset against the Group’s provision for the Samarco dam failure. A short-term facility of up to US$76 million will be made available to Samarco to carry out remediation and stablisation work and to support Samarco’s operations. These funds will be released to Samarco only as required, and subject to achievement of key milestones. For the second half of the 2017 financial year, we are not yet in a position to provide an update to the ongoing potential financial impacts on BHP Billiton Brasil of the Samarco dam failure. Any financial impacts will continue to be classified as an exceptional item.

The above guidance will be updated should material information or events arise as the Group finalises its financial statements.

On 16 June 2017, the BHP Board elected Ken MacKenzie to succeed Jac Nasser as Chairman. Mr MacKenzie will assume the role of Chairman effective 1 September 2017, following Mr Nasser’s retirement as both Chairman and a Non-executive Director.

In July 2017, BHP filed an amendment to its 2016 20-F (2016 20-F/A) to restate its 2016 report on internal controls over financial reporting, as deficiencies were identified in the controls and processes that were used to determine the impairments of certain Onshore US assets. The identified deficiencies did not require any change to the carrying values of the Company’s Onshore US assets at 31 December 2016 or any prior period and there is no need for a restatement of any of the Group’s financial statements. A remediation plan has been implemented and we expect to confirm the controls are operating effectively as part of the 2017 financial year annual reporting process.

Marketing update

The average realised prices achieved for our major commodities are summarised in the table below. The majority of iron ore shipments were linked to the index price for the month of shipment, with price differentials predominantly a reflection of product quality and market fundamentals. The majority of metallurgical coal and energy coal exports were linked to the index price for the month of shipment or sold on the spot market at fixed or index-linked prices, with price differentials reflecting product quality.


Average realised prices⁽ⁱ⁾	Jun H17		Dec H16		FY17		FY16		FY17 vs FY16			Jun H17 vs Jun H16			Jun H17 vs Dec H16
Oil (crude and condensate) (US$/bbl)		50		45		48		39		23	%		35	%		11	%
Natural gas (US$/Mscf)⁽ⁱⁱ⁾		3.48		3.21		3.34		2.83		18	%		27	%		8	%
US natural gas (US$/Mscf)		2.98		2.79		2.88		2.16		33	%		52	%		7	%
LNG (US$/Mscf)		7.37		6.35		6.84		7.71		(11	%)		4	%		16	%
Copper (US$/lb)		2.70		2.41		2.54		2.14		19	%		25	%		12	%
Iron ore (US$/wmt, FOB)		62		55		58		44		32	%		41	%		13	%
Hard coking coal (US$/t)		180		179		180		83		117	%		117	%		1	%
Weak coking coal (US$/t)		121		122		121		69		75	%		73	%		(1	%)
Thermal coal (US$/t)⁽ⁱⁱⁱ⁾		75		74		75		48		56	%		63	%		1	%
Nickel metal (US$/t)		9,799		10,581		10,184		9,264		10	%		11	%		(7	%)

(i)

Based on provisional, unaudited estimates. Prices exclude 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. In Copper, the adjustment will increase Underlying EBITDA by US$27 million in the 2017 financial year.

(ii)	Includes internal sales.

(iii)

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

At 30 June 2017, the Group had 254 kt of outstanding copper sales that were revalued at a weighted average price of US$2.69 per pound. The final price of these sales will be determined in the 2018 financial year. In addition, 316 kt of copper sales from the 2016 financial year were subject to a finalisation adjustment in the current period. The provisional pricing and finalisation adjustments will increase Underlying EBITDA⁽²⁾ by US$27 million in the 2017 financial year.


BHP Operational Review for the year ended 30 June 2017		3

Petroleum

Production


	FY17		Jun 2017 Qtr		FY17 vs FY16			Jun Q17 vs Jun Q16			Jun Q17 vs Mar Q17
Crude oil, condensate and natural gas liquids (MMboe)		97		24		(16	%)		(9	%)		(3	%)
Natural gas (bcf)		668		167		(10	%)		(6	%)		8	%

Total petroleum production (MMboe)		208		52		(13	%)		(7	%)		3	%

Total petroleum production – Total petroleum production for the 2017 financial year decreased by 13 per cent to 208 MMboe.

Petroleum production is forecast to decrease to between 180 and 190 MMboe in the 2018 financial year.

In Onshore US, volumes are expected to decline to between 61 and 67 MMboe as production from the phased ramp-up of development activity is more than offset by natural field decline. The expanded rig program is forecast to deliver production growth of approximately 35 per cent in the 2019 financial year, with investment plans subject to market conditions.

In our Conventional business, volumes are expected to decrease to between 119 and 123 MMboe as infill drilling and brownfield projects are more than offset by planned maintenance at Mad Dog and natural field decline across the portfolio.

Crude oil, condensate and natural gas liquids – Production for the 2017 financial year decreased by 16 per cent to 97 MMboe.

Onshore US liquids volumes decreased by 29 per cent to 34 MMboe as value accretive deferral of activity in the Black Hawk and natural field decline across all fields were partially offset by increased production from the Permian.

Conventional liquids volumes decreased by eight per cent to 63 MMboe as an additional infill well at Mad Dog and higher production at North West Shelf and Algeria partially offset planned maintenance at Atlantis and natural field decline across the portfolio.

Natural gas – Production for the 2017 financial year declined by 10 per cent to 668 bcf.

Divestment of our Pakistan gas business in December 2015 and lower Onshore US gas volumes as a result of deferred development activity for value, were partially offset by strong performance at Bass Strait and Macedon and increased LNG volumes at North West Shelf.

Projects

Project and ownership

Capital
expenditure
(US$m)

Initial
production
target date

Capacity

Progress

North West Shelf Greater Western Flank-B

(Australia)

16.67% (non-operator)

314

CY19

To maintain LNG plant throughput from the North West Shelf operations.

On schedule and budget. The overall project is 47% complete.

Mad Dog Phase 2

(US Gulf of Mexico)

23.9% (non-operator)

2,154

CY22

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

On schedule and budget. The overall project is 3% complete.

Petroleum capital expenditure for the 2017 financial year declined by approximately 41 per cent to US$1.5 billion. In the 2018 financial year we expect an increase to approximately US$2.0 billion (including higher forecast capital creditor movements of approximately US$0.2 billion, the majority relating to Onshore US). This includes Conventional capital expenditure of US$0.8 billion, which remains focused on high-return infill drilling opportunities in the Gulf of Mexico, a life extension project at North West Shelf along with investments related to the recently approved Mad Dog Phase 2 project.


BHP Operational Review for the year ended 30 June 2017		4

Onshore US development activity

Onshore US drilling and development expenditure for the 2017 financial year was approximately US$554 million. During the June 2017 quarter, our operated rig count increased to five, as two additional rigs commenced operations in the Haynesville.


FY17 (FY16)		Liquids focused areas				Gas focused areas
FY17 (FY16)		Eagle Ford		Permian		Haynesville		Fayetteville		Total
Capital expenditure⁽ⁱ⁾	US$ billion		0.3 (0.8)		0.2 (0.4)		0.1 (0.0)		0.0 (0.0)		0.6 (1.2)
Rig allocation	At period end		1 (2)		1 (2)		3 (0)		0 (0)		5 (4)
Net wells drilled and completed⁽ⁱⁱ⁾	Period total		51 (89)		21 (30)		5 (5)		2 (11)		79 (136)
Net productive wells	At period end		963 (929)		126 (107)		394 (411)		1,044 (1,086)		2,527 (2,533)

(i)	Includes land acquisition, site preparation, drilling, completions, well site facilities, mid-stream infrastructure and pipelines.

(ii)	Can vary between periods based on changes in rig activity and the inventory of wells drilled but not yet completed at period end.

Onshore US capital expenditure is expected to be approximately US$1.2 billion in the 2018 financial year. Our plan considers up to five additional rigs.

•

Evaluation of trials in the Black Hawk are expected to be completed in the September 2017 quarter and, subject to approval, one additional rig will commence toward the end of that quarter.

•

One rig has recently commenced operations in the Hawkville executing a 14 well program that will include a mix of completion trials and acreage retention drilling.

•

In the Permian, the current rig will focus on near-term lease obligations while an additional one to two rigs will continue to focus on completion trials that will inform a transition to full pad development as early as the 2019 financial year.

•

One additional rig is expected to commence in the Haynesville in the September 2017 quarter. Further, our hedging strategy allows us to reduce price risk and secure average rates of return in excess of 20 per cent.

•

At this point we do not anticipate any operated development in the Fayetteville, however we continue to work with joint venture partners to assess the potential of the Moorefield horizon through non-operated activity.

The divestment of non-core acreage for value is progressing, with the sale of a portion of the southern Hawkville anticipated to be executed in the September 2017 quarter. Our Fayetteville acreage is currently under review and we are considering all options including divestment.

Petroleum exploration

Exploration and appraisal wells drilled during the June 2017 quarter are summarised below.

Well

Location

Target

BHP equity

Spud date

Water depth

Total well
depth

Status

Wildling-2

US Gulf of Mexico

GC520

Oil

100%

(Operator)

15 April 2017

1,267 m

8,928 m

Drilling ahead

The Wildling-2 well was spud on 15 April 2017 and drilling is in progress, with results expected in the September 2017 quarter. The Scimitar exploration well is expected to be spud in the September 2017 quarter.

In Mexico, BHP has commenced working in partnership with Pemex to plan and execute, during the next 24 months, the Minimum Work Program for blocks AE-0092 and AE-0093 consisting of one appraisal well, one exploration well and the acquisition of additional seismic data.

In Trinidad and Tobago, we continued appraisal work to assess the potential commercialisation of the gas discovery at LeClerc and to prepare for deepwater oil exploration in Phase 2, which is expected to commence in the second half of the 2018 financial year.

In the US Gulf of Mexico, BHP was the apparent high bidder on two leases adjacent to the Scimitar prospect (GC260 and GC304) in the Central Gulf of Mexico Lease Sale 247. BHP (28.32 per cent equity interest), with BP (Operator), was the apparent high bidder on two leases adjacent to the Mad Dog field (GC738 and GC870). All four leases were awarded by the Regulator during the June 2017 quarter.


BHP Operational Review for the year ended 30 June 2017		5

In Australia, BHP has completed its evaluation of the WA-480-P permit in the Northern Beagle sub-basin and has elected to exit this exploration permit. Acquisition of the seismic survey in the Exmouth sub-basin was completed on 1 May 2017. Processed data will be delivered during the June 2018 quarter.

Petroleum exploration expenditure for the 2017 financial year was US$805 million, of which US$473 million was expensed. We are pursuing high-quality oil plays in our priority basins and an US$840 million exploration program is planned for the 2018 financial year taking advantage of low rig rates. This program includes one well in the US Gulf of Mexico, three wells in Trinidad and Tobago, and one well in Mexico.


BHP Operational Review for the year ended 30 June 2017		6

Copper

Production


	FY17		Jun 2017 Qtr		FY17 vs FY16			Jun Q17 vs Jun Q16			Jun Q17 vs Mar Q17
Copper (kt)		1,326		387		(16	%)		(6	%)		71	%
Zinc (t)		87,502		29,076		58	%		349	%		41	%
Uranium oxide concentrate (t)		3,661		737		(16	%)		(16	%)		(22	%)

Copper – Total copper production for the 2017 financial year decreased by 16 per cent to 1.3 Mt. Total copper production is forecast to increase to between 1,655 and 1,790 kt in the 2018 financial year.

Escondida copper production for the 2017 financial year decreased by 21 per cent to 772 kt. The decrease was due to: a four day site-wide suspension of operations following a fatality in October 2016, 44 days of industrial action in the March 2017 quarter and severe weather in early June 2017, reducing production by 21 kt, 214 kt and 12 kt, respectively. Copper production of between 1,130 and 1,230 kt is expected in the 2018 financial year, supported by the ramp-up of the Los Colorados Extension project during the September 2017 quarter, enabling utilisation of three concentrators.

Pampa Norte copper production for the 2017 financial year increased by one per cent to 254 kt, supported by record cathode production and ore milled at Spence following the completion of the Recovery Optimisation project. Pampa Norte copper production for the 2018 financial year is expected to be higher than the prior year.

Olympic Dam copper production for the 2017 financial year decreased by 18 per cent to 166 kt following the state-wide power outage during September and October 2016 and unplanned maintenance at the refinery during December 2016 and January 2017. Copper production of 150 kt is expected in the 2018 financial year as a major smelter maintenance campaign is phased through August to November 2017, including a rebuild of the electric slag furnace, the flash furnace and the electro static precipitator. This is the largest maintenance program undertaken by BHP at Olympic Dam and on completion, the improved operational performance will underpin an expected increase in copper production to approximately 215 kt in the 2019 financial year. This will provide a stable base for the potential to increase capacity to 280 kt in the 2022 financial year.

Antamina copper production for the 2017 financial year decreased by nine per cent to 134 kt as record material mined was more than offset by lower copper grades as mining progressed through a zinc rich ore zone. Copper production is expected to decrease in the 2018 financial year to approximately 125 kt, as mining continues through a zinc rich ore zone consistent with the mine plan. Zinc production is expected to increase from 88 kt to approximately 100 kt in the 2018 financial year.


BHP Operational Review for the year ended 30 June 2017		7

Iron Ore

Production


	FY17		Jun 2017 Qtr		FY17 vs FY16			Jun Q17 vs Jun Q16			Jun Q17 vs Mar Q17
Iron ore⁽ⁱ⁾ (kt)		231,352		60,141		4	%		8	%		12	%

(i)	Represents Western Australia Iron Ore (WAIO). Excludes production from Samarco.

Iron ore – Total iron ore production for the 2017 financial year increased by four per cent to 231 Mt, or 268 Mt on a 100 per cent basis. WAIO production is expected to increase to between 239 and 243 Mt, or between 275 and 280 Mt on a 100 per cent basis, in the 2018 financial year. BHP will continue to work with the relevant authorities to obtain the necessary approvals to increase system capacity to 290 Mtpa (100 per cent basis).

Record annual production of 268 Mt (100 per cent basis) at WAIO reflects strong productivity improvements across the supply chain as well as the commissioning of a new primary crusher and additional conveying capacity at Jimblebar. Following recovery from the wet season, WAIO produced at a record annualised rate of 280 Mt (100 per cent basis) in the June 2017 quarter. The rail renewal and maintenance program was completed in May 2017.

In June 2017, BHP approved initial funding of US$184 million (BHP share) for the South Flank sustaining mine project. The initial funding will be used primarily for the expansion of accommodation facilities to support construction and future operational workforce requirements. The South Flank project, which will leverage and expand the existing Mining Area C hub, is BHP’s preferred option to replace production from the 80 Mtpa (100 per cent basis) Yandi mine when it reaches the end of its economic life in the early-to-mid 2020s. The project is expected to be submitted for Board approval in the middle of the 2018 calendar year and, if approved, first ore is targeted in the 2021 calendar year with ramp-up timed to coincide with the ramp-down of Yandi. The capital cost for South Flank is expected to be in the range of US$30 to US$40 per tonne, with expenditure fitting within WAIO’s previously indicated average annual sustaining capital expenditure of US$4 per tonne over the next five years.

Mining and processing operations at Samarco remain suspended following the failure of the Fundão tailings dam and Santarém water dam on 5 November 2015.


BHP Operational Review for the year ended 30 June 2017		8

Coal

Production


	FY17		Jun 2017 Qtr		FY17 vs FY16			Jun Q17 vs Jun Q16			Jun Q17 vs Mar Q17
Metallurgical coal⁽ⁱ⁾ (kt)		39,770		8,494		(6	%)		(27	%)		(16	%)
Energy coal⁽ⁱⁱ⁾ (kt)		29,135		8,186		7	%		30	%		10	%

(i)	Represents Queensland Coal. Excludes production from Haju following the divestment of IndoMet Coal (2017 financial year: 129 kt).

(ii)	Excludes production from New Mexico Coal following divestments (2017 financial year: 451 kt).

Metallurgical coal – Metallurgical coal production for the 2017 financial year decreased by six per cent to 40 Mt. Production is expected to increase to between 44 and 46 Mt in the 2018 financial year.

At Queensland Coal, production for the 2017 financial year was lower as a result of damage caused by Cyclone Debbie to the network infrastructure of rail track provider Aurizon. Mine operations recovered quickly after the cyclone, as dewatering infrastructure installed after the 2011 floods worked as designed. Force majeure was declared for all Queensland Coal products on 5 April 2017 and was lifted on 1 July 2017.

Despite the impacts of Cyclone Debbie, Peak Downs and Saraji achieved record annual production underpinned by improved stripping and mining performance, and utilisation of latent wash-plant capacity, including approximately 2 Mt trucked to Caval Ridge (100 per cent). Three additional mines were on track for record production prior to Cyclone Debbie.

The Caval Ridge Southern Circuit latent capacity project is progressing according to plan, with production expected to ramp-up early in the 2019 financial year.

Energy coal – Energy coal production for the 2017 financial year increased by seven per cent to 29 Mt. Production is expected to remain broadly unchanged at approximately 29 to 30 Mt in the 2018 financial year.

New South Wales Energy Coal production increased by six per cent as it benefitted from a lower strip ratio and additional bypass coal. Cerrejón production increased by nine per cent compared to the prior year, which was constrained by drought conditions.


BHP Operational Review for the year ended 30 June 2017		9

Other

Nickel production


	FY17		Jun 2017 Qtr		FY17 vs FY16			Jun Q17 vs Jun Q16			Jun Q17 vs Mar Q17
Nickel (kt)		85.1		25.2		5	%		8	%		33	%

Nickel – Nickel West production for the 2017 financial year increased by five per cent to 85.1 kt. Debottlenecking activities at the Kwinana refinery have resulted in record refined metal production. Nickel production for the 2018 financial year is expected to remain broadly unchanged from the 2017 financial year.

Potash project


Project and ownership	Investment (US$m)		Scope	Progress

Jansen Potash (Canada) 100%		2,600	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 70% complete and within the approved budget. Shaft excavation is progressing.

Minerals exploration

Minerals exploration expenditure for the 2017 financial year was US$163 million, of which US$139 million was expensed. Greenfield minerals exploration is predominantly focused on advancing copper targets within Chile, Peru, Canada, South Australia and the South-West United States. BHP was awarded five exploration concessions in Ecuador in June 2017.

Variance analysis relates to the relative performance of BHP and/or its operations during the 2017 financial year compared with the 2016 financial 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. Copper equivalent production based on 2017 financial year average realised prices.

The following footnotes apply to this Operational Review:

(1)	Excludes production from Samarco, Haju (IndoMet Coal) and New Mexico Coal.

(2)

Underlying EBITDA and Underlying attributable profit are used to reflect the underlying performance of BHP. Underlying EBITDA is earnings before net finance costs, taxation, depreciation, amortisation, impairment and any exceptional items. Underlying attributable profit is Attributable profit excluding any exceptional items.

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 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 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).


BHP Operational Review for the year ended 30 June 2017		10

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


Media Relations Australia and Asia Ben Pratt Tel: +61 3 9609 3672 Mobile: +61 419 968 734 Email: Ben.Pratt@bhpbilliton.com Fiona Hadley Tel: +61 3 9609 2211 Mobile: +61 427 777 908 Email: Fiona.Hadley@bhpbilliton.com Amanda Saunders Tel: +61 3 9609 3985 Mobile: +61 417 487 973 Email: Amanda.Saunders@bhpbilliton.com Kester Hubbard Tel: +61 7 3227 5671 Mobile: +61 408 727 261 Email: Kester.Hubbard@bhpbilliton.com United Kingdom and South Africa Neil Burrows Tel: +44 20 7802 7484 Mobile: +44 7786 661 683 Email: Neil.Burrows@bhpbilliton.com North America Bronwyn Wilkinson Mobile: +1 604 340 8753 Email: Bronwyn.Wilkinson@bhpbilliton.com		Investor Relations Australia and Asia Tara Dines Tel: +61 3 9609 2222 Mobile: +61 499 249 005 Email: Tara.Dines@bhpbilliton.com Andrew Gunn Tel: +61 3 9609 3575 Mobile: +61 402 087 354 Email: Andrew.Gunn@bhpbilliton.com United Kingdom and South Africa Rob Clifford Tel: +44 20 7802 4131 Mobile: +44 7788 308 844 Email: Rob.Clifford@bhpbilliton.com Elisa Morniroli Tel: +44 20 7802 7611 Mobile: +44 7825 926 646 Email: Elisa.Morniroli@bhpbilliton.com Americas James Wear Tel: +1 713 993 3737 Mobile: +1 347 882 3011 Email: James.Wear@bhpbilliton.com Cristian Coloma Tel: +1 713 235 8902 Mobile: +1 346 234 8483 Email: Cristian.CA.Coloma@bhpbilliton.com

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BHP Operational Review for the year ended 30 June 2017		11


Production summary

	BHP interest			Quarter ended										Year to date
	BHP interest			Jun 2016		Sep 2016		Dec 2016		Mar 2017		Jun 2017		Jun 2017		Jun 2016
Petroleum ⁽¹⁾
Petroleum
Crude oil, condensate and NGL (Mboe)
Onshore US					9,469		8,288		8,143		9,439		8,501		34,371		48,181
Conventional					16,896		15,959		15,768		15,369		15,612		62,708		67,858

Total					26,365		24,247		23,911		24,808		24,113		97,079		116,039


Natural gas (bcf)
Onshore US					82.0		73.9		67.8		66.1		67.2		275.0		364.5
Conventional					95.7		107.8		97.1		88.4		99.5		392.8		380.2

Total					177.7		181.7		164.9		154.5		166.7		667.8		744.7



Total petroleum production (MMboe)					56.0		54.5		51.4		50.6		51.9		208.4		240.1


Copper ⁽²⁾
Copper
Payable metal in concentrate (kt)
Escondida ⁽³⁾		57.5	%		182.7		147.0		162.6		67.6		162.4		539.6		648.9
Antamina		33.8	%		38.7		34.1		32.0		29.2		38.5		133.8		146.4

Total					221.4		181.1		194.6		96.8		200.9		673.4		795.3


Cathode (kt)
Escondida ⁽³⁾		57.5	%		85.3		70.5		71.5		27.2		62.8		232.0		330.3
Pampa Norte ⁽⁴⁾		100	%		65.8		62.1		53.8		66.1		72.3		254.3		251.4
Olympic Dam		100	%		40.7		40.9		37.2		36.8		51.4		166.3		202.8

Total					191.8		173.5		162.5		130.1		186.5		652.6		784.5



Total copper (kt)					413.2		354.6		357.1		226.9		387.4		1,326.0		1,579.8


Lead
Payable metal in concentrate (t)
Antamina		33.8	%		645		1,146		1,220		1,308		1,799		5,473		3,719

Total					645		1,146		1,220		1,308		1,799		5,473		3,719


Zinc
Payable metal in concentrate (t)
Antamina		33.8	%		6,474		15,367		22,406		20,653		29,076		87,502		55,438

Total					6,474		15,367		22,406		20,653		29,076		87,502		55,438


Gold
Payable metal in concentrate (troy oz)
Escondida ⁽³⁾		57.5	%		35,894		27,561		37,784		11,572		33,941		110,858		108,996
Olympic Dam (refined gold)		100	%		20,010		24,366		29,651		21,941		28,188		104,146		117,686

Total					55,904		51,927		67,435		33,513		62,129		215,004		226,682


Silver
Payable metal in concentrate (troy koz)
Escondida ⁽³⁾		57.5	%		1,874		1,229		1,323		540		1,234		4,326		5,561
Antamina		33.8	%		1,558		1,345		1,446		1,301		1,691		5,783		6,711
Olympic Dam (refined silver)		100	%		232		163		188		174		243		768		917

Total					3,664		2,737		2,957		2,015		3,168		10,877		13,189


Uranium
Payable metal in concentrate (t)
Olympic Dam		100	%		876		916		1,060		948		737		3,661		4,363

Total					876		916		1,060		948		737		3,661		4,363


Molybdenum
Payable metal in concentrate (t)
Antamina		33.8	%		562		561		225		30		328		1,144		1,113

Total					562		561		225		30		328		1,144		1,113


BHP Operational Review for the year ended 30 June 2017		12


Production summary

	BHP interest			Quarter ended										Year to date
	BHP interest			Jun 2016		Sep 2016		Dec 2016		Mar 2017		Jun 2017		Jun 2017		Jun 2016
Iron Ore
Iron Ore
Production (kt) ⁽⁵⁾
Newman		85	%		15,115		18,008		17,751		16,283		16,241		68,283		65,941
Area C Joint Venture		85	%		11,911		12,384		12,179		11,165		13,016		48,744		46,799
Yandi Joint Venture		85	%		18,325		15,729		17,555		14,656		17,415		65,355		67,375
Jimblebar ⁽⁶⁾		85	%		5,304		6,057		5,178		4,824		5,891		21,950		18,890
Wheelarra		85	%		4,971		5,409		7,386		6,647		7,578		27,020		22,549
Samarco		50	%		—		—		—		—		—		—		5,404

Total					55,626		57,587		60,049		53,575		60,141		231,352		226,958


Coal
Metallurgical coal
Production (kt) ⁽⁷⁾
BMA		50	%		9,225		8,384		8,684		7,996		6,394		31,458		33,413
BHP Mitsui Coal ⁽⁸⁾		80	%		2,345		2,145		1,929		2,138		2,100		8,312		8,898
Haju ⁽⁹⁾		75	%		260		102		27		—		—		129		529

Total					11,830		10,631		10,640		10,134		8,494		39,899		42,840


Energy coal
Production (kt)
USA		100	%		632		451		—		—		—		451		7,052
Australia		100	%		3,991		3,952		3,851		4,662		5,711		18,176		17,101
Colombia		33.3	%		2,329		2,928		2,800		2,756		2,475		10,959		10,094

Total					6,952		7,331		6,651		7,418		8,186		29,586		34,247


Other
Nickel
Saleable production (kt)
Nickel West		100	%		23.4		18.8		22.1		19.0		25.2		85.1		80.7

Total					23.4		18.8		22.1		19.0		25.2		85.1		80.7

(1)	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 MMboe.

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

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

(4)	Includes Cerro Colorado and Spence.

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

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

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

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

(9)	Shown on a 100% basis. BHP interest in saleable production is 75%.

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


BHP Operational Review for the year ended 30 June 2017		13


Production and sales report

		Quarter ended										Year to date
		Jun 2016		Sep 2016		Dec 2016		Mar 2017		Jun 2017		Jun 2017		Jun 2016
Petroleum ⁽¹⁾
Bass Strait
Crude oil and condensate	(Mboe)		1,745		1,922		1,770		1,355		1,552		6,599		6,825
NGL	(Mboe)		1,831		2,102		1,460		1,236		1,661		6,459		6,684
Natural gas	(bcf)		38.1		41.9		31.3		28.7		37.4		139.3		131.0

Total petroleum products	(MMboe)		9.9		11.0		8.4		7.4		9.4		36.3		35.3


North West Shelf
Crude oil and condensate	(Mboe)		925		1,486		1,468		1,239		1,314		5,507		4,834
NGL	(Mboe)		241		292		263		200		209		964		962
Natural gas	(bcf)		27.6		38.7		36.9		32.2		32.5		140.3		130.2

Total petroleum products	(MMboe)		5.8		8.2		7.9		6.8		6.9		29.9		27.5


Pyrenees
Crude oil and condensate	(Mboe)		2,097		1,676		1,726		1,509		1,606		6,517		8,617

Total petroleum products	(MMboe)		2.1		1.7		1.7		1.5		1.6		6.5		8.6


Other Australia ⁽²⁾
Crude oil and condensate	(Mboe)		9		10		8		8		9		35		39
Natural gas	(bcf)		17.2		17.5		17.1		15.2		16.3		66.1		64.4

Total petroleum products	(MMboe)		2.9		2.9		2.9		2.5		2.7		11.1		10.8


Atlantis ⁽³⁾
Crude oil and condensate	(Mboe)		4,058		3,054		3,263		3,881		3,637		13,835		16,008
NGL	(Mboe)		269		208		207		295		213		923		1,048
Natural gas	(bcf)		1.9		1.5		1.6		2.1		1.9		7.1		7.4

Total petroleum products	(MMboe)		4.6		3.5		3.7		4.5		4.2		15.9		18.3


Mad Dog ⁽³⁾
Crude oil and condensate	(Mboe)		1,134		950		1,170		1,185		1,167		4,472		3,250
NGL	(Mboe)		52		36		52		59		68		215		157
Natural gas	(bcf)		0.2		0.1		0.2		0.2		0.2		0.7		0.5

Total petroleum products	(MMboe)		1.2		1.0		1.3		1.3		1.3		4.8		3.5


Shenzi ⁽³⁾
Crude oil and condensate	(Mboe)		2,813		2,632		2,692		2,675		2,588		10,587		12,369
NGL	(Mboe)		192		94		131		161		179		565		903
Natural gas	(bcf)		0.6		0.5		0.5		0.5		0.6		2.1		2.7

Total petroleum products	(MMboe)		3.1		2.8		2.9		2.9		2.9		11.5		13.7


Eagle Ford ⁽⁴⁾
Crude oil and condensate	(Mboe)		4,949		3,871		4,008		5,451		4,278		17,608		26,823
NGL	(Mboe)		2,717		2,268		2,159		2,354		2,240		9,021		13,971
Natural gas	(bcf)		19.5		16.5		15.2		17.0		15.1		63.8		95.8

Total petroleum products	(MMboe)		10.9		8.9		8.7		10.6		9.0		37.3		56.8


Permian ⁽⁴⁾
Crude oil and condensate	(Mboe)		1,410		1,415		1,378		1,202		1,336		5,331		5,744
NGL	(Mboe)		393		734		580		428		646		2,388		1,642
Natural gas	(bcf)		4.9		4.4		4.4		4.0		6.2		19.0		14.6

Total petroleum products	(MMboe)		2.6		2.9		2.7		2.3		3.0		10.9		9.8


Haynesville ⁽⁴⁾
Crude oil and condensate	(Mboe)		—		—		3		1		1		5		1
NGL	(Mboe)		—		—		15		3		—		18		—
Natural gas	(bcf)		31.1		28.2		24.0		22.0		21.4		95.6		136.6

Total petroleum products	(MMboe)		5.2		4.7		4.0		3.7		3.6		16.0		22.8


Fayetteville ⁽⁴⁾
Natural gas	(bcf)		26.5		24.8		24.2		23.1		24.5		96.6		117.5

Total petroleum products	(MMboe)		4.4		4.1		4.0		3.9		4.1		16.1		19.6


BHP Operational Review for the year ended 30 June 2017		14


Production and sales report

		Quarter ended										Year to date
		Jun 2016		Sep 2016		Dec 2016		Mar 2017		Jun 2017		Jun 2017		Jun 2016
Petroleum ⁽¹⁾ (continued)

Trinidad/Tobago
Crude oil and condensate	(Mboe)		162		140		156		127		139		562		709
Natural gas	(bcf)		8.6		6.4		8.4		8.4		9.4		32.6		31.0

Total petroleum products	(MMboe)		1.6		1.2		1.6		1.5		1.7		6.0		5.9


Other Americas ^(3) (5)
Crude oil and condensate	(Mboe)		308		275		269		257		238		1,039		1,363
NGL	(Mboe)		10		1		5		6		10		22		50
Natural gas	(bcf)		0.2		0.1		0.1		0.1		0.1		0.4		0.8

Total petroleum products	(MMboe)		0.4		0.3		0.3		0.3		0.3		1.1		1.5


UK
Crude oil and condensate	(Mboe)		76		69		63		72		64		268		274
NGL	(Mboe)		10		22		49		32		16		119		43
Natural gas	(bcf)		1.3		1.1		1.0		1.0		1.1		4.2		4.3

Total petroleum products	(MMboe)		0.3		0.3		0.3		0.3		0.3		1.1		1.0


Algeria
Crude oil and condensate	(Mboe)		964		990		1,016		1,072		942		4,020		3,689

Total petroleum products	(MMboe)		1.0		1.0		1.0		1.1		0.9		4.0		3.7


Pakistan ⁽⁶⁾
Crude oil and condensate	(Mboe)		—		—		—		—		—		—		42
Natural gas	(bcf)		—		—		—		—		—		—		7.9

Total petroleum products	(MMboe)		—		—		—		—		—		—		1.4


BHP Petroleum
Crude oil and condensate
Onshore US	(Mboe)		6,359		5,286		5,389		6,654		5,615		22,944		32,568
Conventional ⁽⁷⁾	(Mboe)		14,291		13,204		13,601		13,380		13,256		53,441		58,011

Total	(Mboe)		20,650		18,490		18,990		20,034		18,871		76,385		90,579


NGL
Onshore US	(Mboe)		3,110		3,002		2,754		2,785		2,886		11,427		15,613
Conventional	(Mboe)		2,605		2,755		2,167		1,989		2,356		9,267		9,847

Total	(Mboe)		5,715		5,757		4,921		4,774		5,242		20,694		25,460


Natural gas
Onshore US	(bcf)		82.0		73.9		67.8		66.1		67.2		275.0		364.5
Conventional	(bcf)		95.7		107.8		97.1		88.4		99.5		392.8		380.2

Total	(bcf)		177.7		181.7		164.9		154.5		166.7		667.8		744.7


Total petroleum products
Onshore US	(Mboe)		23,136		20,605		19,443		20,456		19,701		80,204		108,931
Conventional ⁽⁷⁾	(Mboe)		32,846		33,926		31,951		30,102		32,195		128,175		131,225

Total	(Mboe)		55,982		54,530		51,394		50,558		51,896		208,379		240,156


(1) Total boe conversions are based on 6 bcf of natural gas equals 1 MMboe. Negative production figures represent finalisation adjustments. (2) Other Australia includes Minerva and Macedon. (3) Gulf of Mexico volumes are net of royalties. (4) Onshore US volumes are net of mineral holder royalties. (5) Other Americas includes Neptune, Genesis and Overriding Royalty Interest. (6) BHP completed the sale of the Pakistan gas business on 31 December 2015. (7) September 2015 includes (8) Mboe for the finalisation adjustment following the cessation of production at Stybarrow on 26 June 2015.


BHP Operational Review for the year ended 30 June 2017		15


Production and sales report

		Quarter ended															Year to date
		Jun 2016			Sep 2016			Dec 2016			Mar 2017			Jun 2017			Jun 2017			Jun 2016
Copper
Metals production is payable metal unless otherwise stated.

Escondida, Chile ⁽¹⁾
Material mined	(kt)		108,037			106,504			90,863			26,045			93,389			316,801			433,274
Sulphide ore milled	(kt)		22,905			20,787			19,866			8,054			18,777			67,484			84,989
Average copper grade	(%)		0.94	%		0.87	%		1.02	%		1.01	%		1.07	%		0.99	%		0.98	%
Production ex mill	(kt)		181.7			153.2			168.6			68.7			167.0			557.5			670.0

Production
Payable copper	(kt)		182.7			147.0			162.6			67.6			162.4			539.6			648.9
Copper cathode (EW)	(kt)		85.3			70.5			71.5			27.2			62.8			232.0			330.3
- Oxide leach	(kt)		31.3			26.8			24.4			8.9			20.3			80.4			117.8
- Sulphide leach	(kt)		54.0			43.7			47.1			18.3			42.5			151.6			212.5

Total copper	(kt)		268.0			217.5			234.1			94.8			225.2			771.6			979.2

Payable gold concentrate	(troy oz)		35,894			27,561			37,784			11,572			33,941			110,858			108,996
Payable silver concentrate	(troy koz)		1,874			1,229			1,323			540			1,234			4,326			5,561

Sales
Payable copper	(kt)		186.6			134.9			172.7			63.7			163.3			534.6			649.7
Copper cathode (EW)	(kt)		83.8			65.6			71.8			39.4			56.0			232.8			329.0
Payable gold concentrate	(troy oz)		35,894			27,561			37,784			11,572			33,941			110,858			108,996
Payable silver concentrate	(troy koz)		1,874			1,229			1,323			540			1,234			4,326			5,561

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

Pampa Norte, Chile
Cerro Colorado
Material mined	(kt)		12,453			13,011			14,286			15,178			15,760			58,235			53,668
Ore milled	(kt)		4,375			3,241			3,342			4,179			4,411			15,173			17,946
Average copper grade	(%)		0.80	%		0.68	%		0.65	%		0.57	%		0.53	%		0.60	%		0.77	%

Production
Copper cathode (EW)	(kt)		24.8			17.1			12.1			16.7			18.8			64.7			77.3

Sales
Copper cathode (EW)	(kt)		25.2			16.4			13.7			15.6			19.8			65.5			76.5

Spence
Material mined	(kt)		21,124			23,638			22,635			22,939			24,230			93,442			88,188
Ore milled	(kt)		4,836			4,713			5,187			5,225			4,968			20,093			19,256
Average copper grade	(%)		1.22	%		1.17	%		1.19	%		1.09	%		1.13	%		1.14	%		1.33	%

Production
Copper cathode (EW)	(kt)		41.0			45.0			41.7			49.4			53.5			189.6			174.1

Sales
Copper cathode (EW)	(kt)		40.9			41.2			41.5			49.0			55.7			187.4			173.6


BHP Operational Review for the year ended 30 June 2017		16


Production and sales report

		Quarter ended															Year to date
		Jun 2016			Sep 2016			Dec 2016			Mar 2017			Jun 2017			Jun 2017			Jun 2016
Copper (continued)
Metals production is payable metal unless otherwise stated.

Antamina, Peru
Material mined (100%)	(kt)		62,793			65,111			61,355			55,771			62,254			244,491			226,899
Sulphide ore milled (100%)	(kt)		14,711			13,522			13,399			11,955			13,229			52,105			55,609
Average head grades
- Copper(%)			0.90	%		0.84	%		0.84	%		0.88	%		1.00	%		0.89	%		0.93	%
- Zinc(%)			0.33	%		0.60	%		0.83	%		0.84	%		0.95	%		0.80	%		0.55	%

Production
Payable copper	(kt)		38.7			34.1			32.0			29.2			38.5			133.8			146.4
Payable zinc	(t)		6,474			15,367			22,406			20,653			29,076			87,502			55,438
Payable silver	(troy koz)		1,558			1,345			1,446			1,301			1,691			5,783			6,711
Payable lead	(t)		645			1,146			1,220			1,308			1,799			5,473			3,719
Payable molybdenum	(t)		562			561			225			30			328			1,144			1,113

Sales
Payable copper	(kt)		42.4			32.8			33.0			30.2			36.9			132.9			145.4
Payable zinc	(t)		3,035			16,043			22,334			23,669			27,936			89,982			54,302
Payable silver	(troy koz)		2,055			1,277			1,388			1,304			1,513			5,482			6,956
Payable lead	(t)		1,108			767			1,100			1,475			1,493			4,835			3,503
Payable molybdenum	(t)		331			648			476			—			—			1,124			803

Olympic Dam, Australia
Material mined ⁽¹⁾	(kt)		1,993			2,204			1,887			1,943			1,974			8,008			8,932
Ore milled	(kt)		2,031			2,279			2,116			2,112			2,097			8,604			9,699
Average copper grade	(%)		2.20	%		1.97	%		2.00	%		2.07	%		2.30	%		2.08	%		2.01	%
Average uranium grade	(kg/t)		0.59			0.60			0.68			0.61			0.58			0.62			0.61

Production
Copper cathode (ER and EW)	(kt)		40.7			40.9			37.2			36.8			51.4			166.3			202.8
Uranium oxide concentrate	(t)		876			916			1,060			948			737			3,661			4,363
Refined gold	(troy oz)		20,010			24,366			29,651			21,941			28,188			104,146			117,686
Refined silver	(troy koz)		232			163			188			174			243			768			917

Sales
Copper cathode (ER and EW)	(kt)		43.9			37.5			41.2			33.5			51.5			163.7			203.1
Uranium oxide concentrate	(t)		778			1,085			883			839			1,298			4,105			3,729
Refined gold	(troy oz)		22,134			21,901			28,234			22,333			24,726			97,194			118,952
Refined silver	(troy koz)		201			184			203			108			251			746			877

(1) Material mined refers to run of mine ore mined and hoisted.


BHP Operational Review for the year ended 30 June 2017		17


Production and sales report

		Quarter ended										Year to date
		Jun 2016		Sep 2016		Dec 2016		Mar 2017		Jun 2017		Jun 2017		Jun 2016
Iron Ore
Iron ore production and sales are reported on a wet tonnes basis.

Pilbara, Australia
Production
Newman	(kt)		15,115		18,008		17,751		16,283		16,241		68,283		65,941
Area C Joint Venture	(kt)		11,911		12,384		12,179		11,165		13,016		48,744		46,799
Yandi Joint Venture	(kt)		18,325		15,729		17,555		14,656		17,415		65,355		67,375
Jimblebar ⁽¹⁾	(kt)		5,304		6,057		5,178		4,824		5,891		21,950		18,890
Wheelarra	(kt)		4,971		5,409		7,386		6,647		7,578		27,020		22,549

Total production	(kt)		55,626		57,587		60,049		53,575		60,141		231,352		221,554

Total production (100%)	(kt)		64,508		66,681		69,730		62,177		69,714		268,302		257,320


Sales
Lump	(kt)		13,054		14,156		14,127		12,804		15,104		56,191		54,323
Fines	(kt)		42,673		42,278		45,447		41,043		46,249		175,017		167,255

Total	(kt)		55,727		56,434		59,574		53,847		61,353		231,208		221,578

Total sales (100%)	(kt)		64,617		65,368		69,196		62,513		71,149		268,226		257,346


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

Samarco, Brazil ⁽¹⁾
Production	(kt)		—		—		—		—		—		—		5,404

Sales	(kt)		94		12		—		35		—		47		6,274

(1) Mining and processing operations remain suspended following the failure of the Fundão tailings dam and Santarém water dam on 5 November 2015.


BHP Operational Review for the year ended 30 June 2017		18


Production and sales report

		Quarter ended										Year to date
		Jun 2016		Sep 2016		Dec 2016		Mar 2017		Jun 2017		Jun 2017		Jun 2016
Coal
Coal production is reported on the basis of saleable product.

Queensland Coal
Production ⁽¹⁾
BMA
Blackwater	(kt)		2,206		1,981		1,855		1,694		1,766		7,296		7,626
Goonyella	(kt)		2,709		2,123		2,204		1,871		1,157		7,355		8,996
Peak Downs	(kt)		1,385		1,520		1,715		1,582		1,238		6,055		5,031
Saraji	(kt)		1,123		1,238		1,307		1,276		913		4,734		4,206
Gregory Joint Venture ⁽²⁾	(kt)		—		—		—		—		—		—		1,329
Daunia	(kt)		684		646		680		674		560		2,560		2,624
Caval Ridge	(kt)		1,118		876		923		899		760		3,458		3,601

Total BMA	(kt)		9,225		8,384		8,684		7,996		6,394		31,458		33,413


BHP Mitsui Coal ⁽³⁾
South Walker Creek	(kt)		1,382		1,341		1,080		1,354		1,348		5,123		5,436
Poitrel	(kt)		963		804		849		784		752		3,189		3,462

Total BHP Mitsui Coal	(kt)		2,345		2,145		1,929		2,138		2,100		8,312		8,898

Total Queensland Coal	(kt)		11,570		10,529		10,613		10,134		8,494		39,770		42,311


Sales
Coking coal	(kt)		8,059		7,240		7,658		7,133		5,496		27,527		30,064
Weak coking coal	(kt)		3,196		2,799		2,659		2,761		2,502		10,721		11,818
Thermal coal	(kt)		310		206		154		96		142		598		927

Total	(kt)		11,565		10,245		10,471		9,990		8,140		38,846		42,809


(1) Production figures include some thermal coal. (2) Longwall mining at Crinum completed during the December 2015 quarter. (3) Shown on a 100% basis. BHP interest in saleable production is 80%.

Haju, Indonesia ⁽¹⁾
Production	(kt)		260		102		27		—		—		129		529

Sales - export	(kt)		239		117		—		—		—		117		239

(1) Shown on 100% basis. BHP interest in saleable production is 75%. BHP completed the sale of IndoMet Coal on 14 October 2016.

New Mexico, USA
Production
Navajo Coal ⁽¹⁾	(kt)		632		451		—		—		—		451		3,999
San Juan Coal ⁽²⁾	(kt)		—		—		—		—		—		—		3,053

Total	(kt)		632		451		—		—		—		451		7,052


Sales thermal coal - local utility			613		105		—		—		—		105		7,051

(1) The divestment of Navajo Coal was completed on 29 July 2016, with no further production reported by BHP. Management of Navajo Coal was transferred to Navajo Transitional Energy Company on 31 December 2016. (2) BHP completed the sale of San Juan Mine on 31 January 2016.

NSW Energy Coal, Australia
Production	(kt)		3,991		3,952		3,851		4,662		5,711		18,176		17,101

Sales
Export thermal coal	(kt)		3,993		3,640		3,539		4,407		4,913		16,499		16,614
Inland thermal coal	(kt)		440		331		311		431		327		1,400		1,156

Total	(kt)		4,433		3,971		3,850		4,838		5,240		17,899		17,770


Cerrejón, Colombia
Production	(kt)		2,329		2,928		2,800		2,756		2,475		10,959		10,094

Sales thermal coal - export(kt)			2,844		2,905		2,722		2,613		2,803		11,043		10,601


BHP Operational Review for the year ended 30 June 2017		19


Production and sales report

		Quarter ended										Year to date
		Jun 2016		Sep 2016		Dec 2016		Mar 2017		Jun 2017		Jun 2017		Jun 2016
Other
Nickel production is reported on the basis of saleable product

Nickel West, Australia
Production
Nickel contained in concentrate	(kt)		0.3		0.3		0.2		0.2		—		0.7		1.5
Nickel contained in finished matte	(kt)		5.8		1.8		4.1		2.3		5.3		13.5		16.2
Nickel metal	(kt)		17.3		16.7		17.8		16.5		19.9		70.9		63.0

Total nickel production	(kt)		23.4		18.8		22.1		19.0		25.2		85.1		80.7


Sales
Nickel contained in concentrate	(kt)		0.3		0.3		0.2		0.2		—		0.7		1.5
Nickel contained in finished matte	(kt)		5.9		1.8		4.1		2.2		4.9		13.0		16.5
Nickel metal	(kt)		17.4		16.5		17.6		17.1		18.1		69.3		62.9

Total nickel sales	(kt)		23.6		18.6		21.9		19.5		23.0		83.0		80.9


BHP Operational Review for the year ended 30 June 2017		20

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.