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
August 16, 2016
| BHP BILLITON LIMITED | BHP BILLITON PLC | |
| (ABN 49 004 028 077) | (REG. NO. 3196209) | |
| (Exact name of Registrant as specified in its charter) | (Exact name of Registrant as specified in its charter) | |
| VICTORIA, AUSTRALIA | ENGLAND AND WALES | |
| (Jurisdiction of incorporation or organisation) | (Jurisdiction of incorporation or organisation) | |
| 171 COLLINS STREET, MELBOURNE, VICTORIA 3000 AUSTRALIA |
NEATHOUSE PLACE, LONDON, UNITED KINGDOM | |
| (Address of principal executive offices) | (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: x 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 x No
If “Yes” is marked, indicate below the file number assigned to the registrant in connection with Rule 12g3-2(b): n/a
| BHP Billiton Limited | BHP Billiton Plc | |||
| 171 Collins Street | Neathouse Place | |||
| Melbourne Victoria 3000 Australia | London SW1V 1LH UK | |||
| GPO BOX 86 | Tel +44 20 7802 4000 | |||
| Melbourne Victoria 3001 Australia | Fax + 44 20 7802 4111 | |||
| Tel +61 1300 55 47 57 Fax +61 3 9609 3015 | bhpbilliton.com | |||
| bhpbilliton.com |
16 August 2016
| To: |
Australian Securities Exchange | |
| New York Stock Exchange |
RESULTS PRESENTATION YEAR ENDED 30 JUNE 2016
Attached are the presentation slides for a presentation that will be given by the Chief Executive Officer and Chief Financial Officer shortly.
The Webcast for this presentation can be accessed at:
http://edge.media-server.com/m/p/fga4tpfi
Further information on BHP Billiton can be found at www.bhpbilliton.com.
|
| Rachel Agnew |
| Company Secretary |
| BHP Billiton Limited ABN 49 004 028 077 | BHP Billiton Plc Registration number 3196209 | |
| Registered in Australia | Registered in England and Wales | |
| Registered Office: Level 18, 171 Collins Street Melbourne Victoria 3000 | Registered Office: Neathouse Place, London SW1V 1LH United Kingdom |
The BHP Billiton Group is headquartered in Australia
bhpbilliton Financial results Year ended 30 June 2016 Olympic Dam
Disclaimer
Forward-looking statements
This presentation contains forward-looking
statements, including statements regarding: trends in commodity prices and currency exchange rates; demand for commodities; plans, strategies and objectives of management; closure or divestment of certain operations or facilities (including
associated costs); anticipated production or construction commencement dates; capital costs and scheduling; operating costs and shortages of materials and skilled employees; anticipated productive lives of projects, mines and facilities; provisions
and contingent liabilities; tax and regulatory developments.
Forward-looking statements can be identified by the use of terminology such as ‘intend’,
‘aim’, ‘project’, ‘anticipate’, ‘estimate’, ‘plan’, ‘believe’, ‘expect’, ‘may’, ‘should’, ‘will’, ‘continue’, ‘annualised’ or
similar words. These statements discuss future expectations concerning the results of operations or financial condition, or provide other forward-looking statements.
These forward-looking statements 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 presentation. Readers are cautioned not to put undue reliance on forward-looking statements.
For example, future revenues from our operations, projects or mines described in this presentation will be based, in part, upon the market price of the minerals,
metals or petroleum produced, which may vary significantly from current levels. These variations, if materially adverse, may affect the timing or the feasibility of the development of a particular project, the expansion of certain facilities or
mines, or the continuation of existing operations.
Other factors that may affect the actual construction or production commencement dates, costs or production
output and anticipated lives of operations, mines or facilities include our ability to profitably produce and transport the minerals, petroleum and/or metals extracted to applicable markets; the impact of foreign currency exchange rates on the
market prices of the minerals, petroleum or metals we produce; activities of government authorities in some of the countries where we are exploring or developing these projects, facilities or mines, including increases in taxes, changes in
environmental and other regulations and political uncertainty; labour unrest; and other factors identified in the risk factors discussed in BHP Billiton’s filings with the US Securities and Exchange Commission (the “SEC”) (including
in Annual Reports on Form 20-F) which are available on the SEC’s website at www.sec.gov.
Except as required by applicable regulations or by law, the Group
does not undertake any obligation to publicly update or review any forward-looking statements, whether as a result of new information or future events. Past performance cannot be relied on as a guide to future performance.
Non-IFRS financial information
BHP Billiton results are reported under International Financial
Reporting Standards (IFRS) including Underlying EBIT and Underlying EBITDA which are used to measure segment performance. This release may also include certain non-IFRS and other financial measures including Adjusted effective tax rate, Free cash
flow, Gearing ratio, Net debt, Net operating assets, Underlying attributable profit, Underlying basic (loss)/earnings per share, Underlying EBIT margin and Underlying EBITDA margin. These measures are used internally by management to assess the
performance of our business, make decisions on the allocation of our resources and assess operational management. Non-IFRS and other financial measures have not been subject to audit or review and should not be considered as an indication of or
alternative to an IFRS measure of profitability, financial performance or liquidity.
Presentation of data
Unless specified otherwise: all data is presented on a continuing operations basis to exclude the contribution from assets that were demerged with South32; references to Underlying
EBITDA margin exclude third party trading activities; data from subsidiaries is shown on a 100 per cent basis and data from equity accounted investments and other operations is shown on a proportionate consolidation basis. Queensland Coal comprises
the BHP Billiton Mitsubishi Alliance (BMA) asset, jointly operated with Mitsubishi, and the BHP Billiton Mitsui Coal (BMC) asset, operated by BHP Billiton. Numbers presented may not add up precisely to the totals provided due to rounding.
No offer of securities
Nothing in this presentation should be construed as
either an offer to sell or a solicitation of an offer to buy or sell BHP Billiton securities in any jurisdiction, or be treated or relied upon as a recommendation or advice by BHP Billiton.
Reliance on third party information
The views expressed in this presentation contain
information that has been derived from publicly available sources that have not been independently verified. No representation or warranty is made as to the accuracy, completeness or reliability of the information. This presentation should not be
relied upon as a recommendation or forecast by BHP Billiton.
Financial results
16 August 2016
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Financial
results
Year ended 30 June 2016
Andrew Mackenzie Chief Executive Officer
South Walker Creek
Solid performance in a challenging year Safety Committed to addressing consequences of the Samarco tailings dam failure Zero fatalities at BHP Billiton operated sites Volume Record WAIO and metallurgical coal production; strong conventional petroleum volumes Offset by anticipated Escondida grade decline and deferral of Onshore US activity Cost Unit cash costs across the Group down 16% from FY151 Productivity gains of US$437 million (gains of US$2.0 billion excluding Escondida grade decline) Financial Underlying EBITDA of US$12.3 billion; Underlying EBITDA margin of 41% results Underlying attributable profit of US$1.2 billion; Attributable loss of US$6.4 billion Cash Net operating cash flow of US$10.6 billion flow Free cash flow2 of US$3.4 billion Balance Net debt of US$26.1 billion sheet Liquidity of US$16.3 billion and long-dated maturity profile Dividend Final dividend of US$0.14 per share Total FY16 dividend determined of US$0.30 per share 1. Presented on a continuing operations basis excluding BHP Billiton’s share of volumes from equity accounted investments; operating cost per copper equivalent tonne calculated using FY16 realised prices. 2. Free cash flow: net operating cash flows less net investing cash flows. Financial results 16 August 2016 4 bhpbilliton
Committed to Samarco
Rehabilitation progressing well
- Germano and Santarem Dams reinforcement
works continue
- 90% of the 41 work programs initiated
- community
resettlement ongoing
Foundation established
- Framework Agreement is the
appropriate long-term response
Expect findings of the external investigation into the cause of the dam failure to be released shortly
Preparation for the wet season a priority
Technical studies indicate Samarco can restart
safely
- completion of stabilisation work, range of permits and community support required
Samarco infrastructure
Santarem Dam, November 2015
Environment
Barra Longa, November 2015
Rebuilt Santarem Dam, March 2016
River stabilisation at Barra Longa,
May 2016
Financial results
16 August 2016
5
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Safety is paramount
The health and safety of our
people and communities always
come first
- tragically 19 lives were lost
following the Samarco dam failure
Strong safety performance at BHP Billiton operated sites
- zero fatalities in FY16
- TRIF of 4.3 per million hours worked
- 20% reduction in high potential safety events
- better investigation quality and learning
from past events
Total Recordable Injury Frequency at operated sites
(number
of recordable injuries per million hours worked1)
10
8
6
4
2
0
FY06 FY07 FY08 FY09 FY10 FY11 FY12 FY13 FY14 FY15 FY16
1. FY06 to FY14 presented on a total operations basis.
Financial results
16 August 2016
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6
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bhpbilliton
Financial results
Year ended 30 June 2016
Peter Beaven Chief Financial Officer
Shenzi
|
Asset quality and operating performance drive margins
Underlying EBITDA of US$12.3 billion
- Underlying EBITDA margin of 41%
- 16% reduction in unit costs
Underlying EBIT of US$3.5 billion
Underlying attributable profit of US$1.2 billion
- Attributable loss of US$6.4 billion
- US$7.7 billion of exceptional items (after tax)
Leading margins through the
cycle
(Underlying EBITDA margin1, %)
60
35
10
FY06 FY07 FY08 FY09 FY10
FY11
FY12
FY13
FY14
FY15
FY16
BHP Billiton
Peer group range
Petroleum
240 MMboe
Conventional cost: US$ 8.53/boe
EBITDA: US$3.7 billion
EBITDA margin: 54%
Copper
1,580 kt
Cost: US$1.20/lb
EBITDA: US$2.6 billion
EBITDA margin: 35%
Iron Ore
227 Mt
Cost2: US$15/t
EBITDA2: US$5.5 billion
EBITDA2 margin: 53%
Metallurgical Coal
43 Mt
Cost2: US$55/t
EBITDA2: US$584 million
EBITDA2 margin: 17%
1. BHP Billiton data for FY06 to FY14 presented on a total operations
basis. Peer group comprises Anglo American, Rio Tinto and Vale.
2. Unit cost, EBITDA and EBITDA margins refer to Western Australia Iron Ore and Queensland Coal.
Financial results
16 August 2016
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Group EBITDA waterfall
Underlying EBITDA variance
(US$ billion)
24
21.9
External (US$9.9 billion)
Controllable US$0.3 billion
16
1.1
0.2
12.3
12.0
1.4
0.2
(0.3)
(0.3)
(10.7)
(0.4)
(0.8)
8
0
FY15
Price1
Foreign exchange
Inflation
Sub-total
Growth volumes
Productivity volumes
Controllable cash costs
Fuel & energy
Non-cash2
Other3
FY16
1. Net of price-linked costs.
2. Non-cash includes deferred stripping depletion.
3. Other includes ceased and sold
operations, asset sales, one-off items and other items (including profit/loss from equity accounted investments).
Financial results
16 August 2016
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Financial impact of Samarco dam failure
Investment in
Samarco written down to US$nil at
31 December 2015
US$1.2 billion provision
at 30 June 2016 reflects uncertainty around potential restart
- equivalent to 50% share of current estimate of Samarco’s funding obligations under terms of
Framework Agreement
- US$134 million funding support to Foundation’s reparatory and compensatory programs will be offset against provision
Direct costs incurred by BHP Billiton1 of US$70 million
Samarco financial support made
available for remediation and stabilisation work and to support operations
- short-term funding facility of US$116 million for restart and working capital will be
released only as required - safe restart is an important priority, along with the restructure of Samarco’s debt
Equity accounted investment in Samarco
Income statement impacts
H1 H2
(US$ million)
FY16 FY16 FY16
Share of loss relating to dam failure &
impairment of carrying value of the
(1,180)
- (1,180)
investment in Samarco
BHP Billiton Brasil provision
- (1,200) (1,200)
Costs incurred directly by BHP Billiton1
(8) (62) (70)
in relation to the Samarco dam failure
Total pre-tax Samarco dam failure
exceptional expense
(1,188) (1,262) (2,450)
Income tax benefit / (expense)
330 (77) 253
Total Samarco dam failure
(858) (1,339) (2,197)
exceptional expense
Balance sheet impacts
H1 H2
(US$ million)
FY15
FY16
FY16
FY16
Investment in Samarco
1,0442
- - -
BHP Billiton Brasil provision
- -
(1,200) (1,200)
1. Includes BHP Billiton Brasil and other BHP Billiton entities.
2. Excludes US$136 million representing share of operating profit prior to the dam failure on 5 November 2015.
Financial results
16 August 2016
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Free cash flow provides optionality
Free cash flow of
US$3.4 billion
- net operating cash flow of US$10.6 billion
- capital and
exploration expenditure of US$7.7 billion1
- working capital release of US$0.2 billion
- ~40% reduction in Group overheads over 4 years2
Balance sheet is strong
- net debt of US$26.1 billion
- average debt maturity of 9 years
- liquidity of US$16.3 billion
- ‘A’ credit rating maintained3
Capital and exploration expenditure (cash basis)
(US$ billion)
24
12
0
FY12 FY13 FY14 FY15 FY16 FY17e
Movements in net debt
(US$ billion)
28 3.3 0.0 25.9 1.4 26.1
24.4 (0.6) 0.9 0.1
24 (1.2) (2.2)
20
FY15
Free cash flow
Dividends paid
Other movements4
Non-cash movement5
H1 FY16
Free cash flow
Dividends paid
Other Movements4
Non-cash movement5
FY16
1. Cash basis. Capital and exploration expenditure of US$6.4 billion on a BHP Billiton share basis.
2. Excludes Samarco and Group capital expenditure.
3. Current credit rating of A (S&P) and
A3 (Moody’s). We manage to a solid A credit rating through the cycle.
4. Includes purchase of shares by Employee Share Ownership Plan Trusts.
5. Non-cash movements include non-cash foreign exchange variance due to the revaluations of local currency denominated debt offset by non-cash fair value adjustment on hedged debt.
Financial results
16 August 2016
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Disciplined capital allocation
Our Capital Allocation
Framework balances value creation, shareholder returns and balance sheet strength
- ‘A’ credit rating maintained1
- total dividends paid of US$4.1 billion
- growth capital and exploration expenditure of
US$5.7 billion
Board will consider additional cash returns over minimum 50% payout at every reporting period
US$0.30 per share dividend determined in FY16
- H1: US$0.16 per share
(US$0.04 plus US$0.12 additional)
- H2: US$0.14 per share
(US$0.08 plus US$0.06 additional)
Capital allocation in FY16
(US$ billion)
H1 H2
FY16
5.3 5.3 10.6
Net operating cash flow
1.0 1.0 2.0
maintenance capital
Solid A credit rating through the cycle
balance sheet
3.32 0.2 3.5
minimum dividend paid
1.0 4.1 5.1
Excess cash
(2.3) 1.3 (0.9)
balance sheet
Maximise returns and value
3.4 2.3 5.7
organic growth investment
- 0.6 0.6
additional dividend amount
-
-
-
buy-backs
(0.1) (0.2) (0.3)
acquisitions/(divestments)
1. Current credit rating of A (S&P) and A3 (Moodys). We manage
to a solid A credit rating through the cycle.
2. Final dividend determined under progressive dividend policy in August 2015.
Financial results
16 August 2016
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Financial
results
Year ended 30 June 2016
Andrew Mackenzie Chief Executive Officer
Eastern Ridge
Well placed for the conditions we expect
Near-term is difficult
- well-supplied markets across our commodity suite
- ineffective monetary policy, political uncertainty, populist rejection of free trade suppressing business confidence
Fundamentals to return as markets rebalance over the medium term
Robust longer-term demand
outlook
- China’s industrial output and fixed investment solid
-
urbanisation, industrialisation and freer trade will lift demand from other emerging markets
| Commodity market outlook to 2025 | ||||
| Petroleum1 | ||||
| Supply opportunity by 2025 (versus 2015) | Copper | |||
| Potash | ||||
| Energy coal | ||||
| Iron ore | ||||
| Metallurgical coal | ||||
| Time until expected market rebalance |
Source: Wood Mackenzie, BHP Billiton analysis.
1.
Includes crude and US gas.
Financial results
16 August 2016
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Focused portfolio and simplified operating model
Optimal portfolio after divestments and demerger
- well-capitalised, low-cost, long-life
assets with expansion options
- diversified across the right commodities
-
favourable geographic concentration
New operating model accelerates productivity gains
- assets focused solely on safety, volume and cost
- globally integrated functions co-located
with the assets
- centres of excellence for maintenance, projects and geoscience
- new structure has lowered overheads through fewer layers and increased spans of control
Tier
1 portfolio (FY16 Underlying EBITDA margin, %) 80 Note: Bubble size represents FY16 copper equivalent production1
Iron ore Petroleum 60 40 Copper Energy coal 20
Metallurgical coal 0 1st 2nd 3rd 4th Cost curve position2 (quartile)
Source: AME; Wood Mackenzie; BHP Billiton analysis.
1. Copper equivalent production based on FY16 realised prices.
2. Based on weighted average
equity share of production using quality-adjusted operating cost curves versus contestable demand in the markets in which our assets operate.
Financial results
16 August 2016
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Broad suite of opportunities offers significant upside
We have made significant progress to capture valuation upside and improve returns
| Productivity | On track to deliver US$2.2 billion of gains over two years to end FY17 | |
| Absorbed US$1.6 billion impact of grade decline at Escondida in FY16 | ||
| Latent | Latent capacity options equate to >10% of current production at a capital cost of ~US$1.5 billion | |
| capacity | Los Colorados Extension approved; Spence Recovery Optimisation ramping up; new Jimblebar capacity | |
| by December; Queensland Coal capacity creep; Olympic Dam on track for 230 ktpa by 2021 | ||
| Shale | Onshore US free cash flow positive in FY17 at consensus prices | |
| Launched hedging program to unlock resource in the Haynesville | ||
| Projects | Mad Dog 2 investment decision expected in the next 12 months | |
| Spence Growth Option due for Board review in H2 CY17; | ||
| Olympic Dam Brownfield Expansion (BFX) now at concept study phase | ||
| Exploration | Counter cyclical investment to accelerate oil and copper exploration | |
| Exploration wells currently drilling in the Gulf of Mexico and Trinidad & Tobago | ||
| Technology | Ongoing investment in technology to lower costs and unlock resources | |
| IROC for Coal approved; Olympic Dam heap leach trials moved to next stage |
Financial results
16 August 2016
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Momentum builds into the new financial year
Steady volumes…
FY17 copper equivalent volume growth of up to 4% (ex-Onshore US)
Onshore US will respond to market conditions
…lower costs…
productivity gains of US$1.8 billion expected in FY17
unit costs expected to
reduce by 12%1
…and higher capital productivity…
FY17 capital and
exploration expenditure of US$5.4 billion2
biased to latent capacity and low-cost growth
…will drive free cash flow and lower debt
free cash flow of over US$7 billion in FY17 at
spot prices3
FY16 net debt of US$26.1 billion expected to be the peak this cycle
Lowest unit operating costs in a decade expected in FY17
(Mt, operating cost per copper
equivalent tonne)
| FY07 | FY08 | FY09 | FY10 | FY11 | FY12 | FY13 | FY14 | FY15 | FY16 | FY17e | ||||||||||
| Volumes1 | Operating cost per copper equivalent tonne¹ |
|||||||||||||||||||
1. Presented on a continuing operations basis excluding BHP Billiton’s share of volumes from equity accounted investments; operating
cost per copper equivalent tonne calculated using FY16 realised prices.
2. On a cash basis. Capital and exploration expenditure of US$5.0 billion on BHP Billiton
share basis.
3. Spot prices at 8 August 2016.
Financial results
16 August 2016
17
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Positioned to grow value and returns
The right commodities…
optimal diversification with petroleum and copper markets expected
to rebalance first
…the right assets…
optimal portfolio of well-capitalised, low-cost, long life assets
…the right
structure…
12 operated assets, 4 commodities, 3 operating groups
…to maximise free cash flow1
free cash flow of over US$7 billion in FY17
at spot prices2
The right capital allocation framework…
balances value
creation, shareholder returns and balance sheet strength
…to drive value and returns
strong progress on suite of opportunities to grow value and improve ROIC
We have opportunities
to significantly increase returns
(Return on Capital Employed3 at consensus prices, nominal)
(Years)
1. Free cash flow: operating cash flow less capital expenditure and exploration.
2. Spot prices at 8 August 2016.
3. Assumes all latent capacity and growth
options (including Onshore US) proceed.
Financial results
16 August 2016
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Appendix
BHP Billiton guidance
Group
FY17e
FY18e
Capital and exploration expenditure (US$bn)
5.4
6.2
Cash basis.
Including:
Maintenance
2.0
Exploration
0.8
0.8
US$700m Petroleum and US$60m Copper exploration program planned for FY17.
Petroleum
FY17e
Total petroleum production (MMboe)
200 - 210
Onshore US
Capital expenditure (US$bn)
0.6
Development activity tailored to market conditions.
Production (MMboe)
77 - 83
We continue to balance near-term cash flow performance and long-term value maximisation.
Conventional Petroleum
Capital expenditure (US$bn)
0.8
Focused on life extension projects at Bass Strait and North West Shelf.
Production (MMboe)
123 - 127
35 day maintenance shutdown at Atlantis in Q1 FY16, deferral of infill drilling in the Gulf of Mexico for value and natural field decline.
Unit cost (US$/barrel)
10
Excludes inventory movements, freight, and third party and exploration expense.
Exploration
(US$bn)
0.7
Focused on Gulf of Mexico, the Caribbean and the Northern beagle
sub-basin.
Financial results
16 August 2016
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BHP Billiton guidance (continued)
Copper
FY17e
Total copper production (Mt)
1.66
Guidance for Escondida at 1.07 Mt. Pampa Norte production is expected to increase. Olympic Dam production guidance to remain unchanged.
Guidance for Antamina production to decrease to 130 kt as planned mining sequence moves through lower a copper grade zone.
Escondida
Production (Mt, 100% basis)
1.07
Enabled by the commissioning of the Escondida Water Supply project and the ramp up of the
Los Colorados Extension.
Unit cash costs (US$/lb)
1.00
Excludes freight and treatment and refining charges. Net of by-product credits. Based on an exchange rate of USD/CLP 698.
Iron Ore
FY17e
Total iron ore production (Mt)
228 - 237
Excludes production from Samarco.
Western Australia Iron Ore
Production (Mt, 100% basis)
265 - 275
Unit cash costs (US$/t)
14
Excludes freight and royalties; based on an exchange rate of AUD/USD 0.71.
Sustaining capital
expenditure (US$/t)
4
Long term average; +/- 50% in any given year.
Coal
FY17e
Total metallurgical coal production (Mt)
44
Total energy coal production (Mt)
30
The divestment of Navajo Coal to Navajo Transitional Energy Company was completed on 29 July 2016.
Queensland Coal
Production (Mt)
44
Unit cash costs (US$/t)
52
Excludes freight and royalties; based on an exchange rate of AUD/USD 0.71.
Sustaining capital expenditure (US$/t)
6
Long term average; +/- 50% in any given year.
NSW Energy Coal
Production (Mt)
19
Unit cash costs (US$/t)
38
Excludes freight and royalties; based on an exchange rate of AUD/USD 0.71.
Sustaining capital
expenditure (US$/t)
4
Long term average; +/- 50% in any given year.
Financial results
16 August 2016
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Key Underlying EBITDA sensitivities
| Approximate impact1 on FY17 Underlying EBITDA of changes of: | US$ million | |
| US$1/t on iron ore price2 | 217 | |
| US$1/bbl on oil price3 | 79 | |
| US¢10/MMbtu on US gas price | 26 | |
| US$1/t on metallurgical coal price | 42 | |
| US¢1/lb on copper price2 | 34 | |
| US$1/t on energy coal price2 | 18 | |
| US¢1/lb on nickel price | 2 | |
| AUD (US¢1/A$) operations4 | 78 |
1. Assumes total volume exposed to price; determined on the basis of BHP Billiton’s existing portfolio.
2. Excludes impact of equity accounted investments.
3. Excludes impact of change in input
costs across the Group.
4. Based on average exchange rate for the period.
Financial results
16 August 2016
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Petroleum EBITDA waterfall
Underlying EBITDA variance
(US$ billion) 8.0 External (US$3.7 billion)
Controllable US$0.2 billion 7.2 0.7 4.0 3.7 3.5 (0.0) (3.6) (0.1) (0.0) 0.0 (0.1) (0.4) 0.0
FY15
Price1
Foreign exchange
Inflation
Sub-total
Growth volumes
Controllable cash costs
Fuel & energy
Non-cash2
Other3
FY16
1. Net of price-linked costs.
2. Non-cash includes change in deferred stripping depletion.
3. Other includes ceased and sold operations, asset sales, one-off items and other items (including profit/loss from equity accounted investments).
Financial results
16 August 2016
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Copper EBITDA waterfall
Underlying EBITDA variance
(US$ billion)
6.0
External (US$2.0 billion)
Controllable (US$0.6 billion)
5.2
0.3
3.2
0.0
3.0
(2.2)
(0.1)
0.2
2.6
0.2
0.0
(0.9)
(0.1)
0.0
FY15
Price1
Foreign exchange
Inflation
Sub-total
Growth volumes
Productivity volumes
Controllable cash costs
Fuel & energy
Non-cash2
Other3
FY16
1. Net of price-linked costs.
2. Non-cash includes change in deferred stripping depletion.
3. Other includes asset sales,
one-off items and other items (including profit/loss from equity accounted investments).
Financial results
16 August 2016
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Iron Ore EBITDA waterfall
Underlying EBITDA variance
(US$ billion) 10.0 External (US$3.4 billion)
Controllable US$0.4 billion 8.6 0.1 0.3 5.6 0.3 5.2 0.0 0.1 (0.0) (0.1) 5.0 (3.6) (0.1) 0.0 FY15 Price1
Foreign exchange Inflation Sub-total Growth volumes
Productivity volumes Controllable cash costs Fuel & energy Non-cash2 Other3
FY16 1. Net of price-linked costs. 2. Non-cash includes change in deferred
stripping depletion. 3. Other includes ceased and sold operations, asset sales, one-off items and other items (including profit/loss from equity accounted investments). Financial results 16 August 2016 26
bhpbilliton
Coal EBITDA waterfall Underlying EBITDA variance (US$ billion) 1.6 External (US$0.6 billion) Controllable
US$0.0 billion 1.2 0.1 0.2 0.0 0.8 0.4 0.6 0.0 0.0 0.6 (0.1) (0.3) (0.9) 0.0 FY15
Price1 Foreign exchange Inflation Sub-total Growth volumes Productivity volumes
Controllable cash costs Fuel & energy Non-cash2 Other3 FY16 1. Net of price-linked costs. 2. Non-cash includes change in deferred stripping depletion. 3. Other includes ceased and sold operations, asset sales, one-off items and other items
(including profit/loss from equity accounted investments). Financial results 16 August 2016 27 bhpbilliton
Other items affecting profitability
Other items
(US$ billion)
Underlying
Underlying EBITDA
attributable profit1
Exceptional items1
0.0
(0.3)
(0.2)
(0.2)
(0.2)
(0.2)
(0.6)
(2.0)
(2.2)
(4.0)
(4.9)
(6.0)
Redundancies and closure costs
Royalty and taxation matters
Redundancies and closure costs
Minor impairments
Royalty and taxation matters
Global taxation matters
Samarco dam failure
Impairment of Onshore US
1. Post tax consequences.
Financial results
16 August 2016
Debt maturity profile
Debt balances1
(US$ billion2)
8
6
4
2
0
FY17 FY18 FY19 FY20 FY21 FY22 FY23 FY24 FY25 FY26 FY27 FY28 Post FY28
US$ Bonds 3Euro Bonds3
Sterling Bonds3 A$ Bonds C$ Bonds Subsidiaries
% of portfolio 46% 30%11%5%2%6%
Capital markets 94% Asset financing 6%
1. All debt balances are represented
in notional US$ values and based on financial years. As at 30 June 2016.
2. Subsidiary debt is presented in accordance with IFRS 10 and IFRS 11.
3. Includes hybrid bonds (18% of portfolio: 9% in US$, 6% in Euro, 3% in Sterling).
Financial
results
16 August 2016
29
bhpbilliton
We remain positive on long-term copper fundamentals
Short-term overcapacity in copper remains persistent
Subdued demand with slower than expected
growth in China and recession in key non-Asian emerging economies
Increased supply from new and expanded operations with more growth expected near term
Long-term fundamentals are sound
Demand growth will continue as China transitions to a
consumer-driven economy, and copper-intensive renewable energy capacity and electric vehicles grow rapidly
Emerging markets will recover and converge to their
natural intensity curves
Grade decline and mine depletions will require investment in new supply
Global demand slow recently, but long run trend is still positive
(Refined copper demand1, Mt)
22.5 CAGR 1.5% 22.0 21.5 CY14
China
RoW
CIS/ S America
CY15
CY15
CY30e
Continued global ore grade decline expected
(Copper grades2, %)
1.5
1.3
1.1
0.9
CY00 CY05 CY10 CY15 CY20e CY25e
Source: Wood Mackenzie.
1. The two upper panels are not set to the same scale.
2. Based on average grade weighted by paid copper.
Financial results
16 August 2016
30
bhpbilliton
Oil and US gas markets expected to rebalance
Outlook remains healthy
Fundamentals tightening, as healthy demand growth intersects with
slower global production growth due to falling production in the US
Rate of inventory drawdown will impact price recovery - OPEC and US production remain key watch
points
Higher prices will be required to induce the new supply needed to offset natural field decline and meet growing demand
Near-term US natural gas prices driven by storage and weather; long-term market supported by robust demand growth
Mild winter, industry-wide productivity gains and resilient supply resulted in record inventory levels
Inventories forecast to return to average levels by end CY16 on strong demand growth and declining production
While investment in new supply sources will be required, the abundant lower-cost supply will moderate price inflation
Oil mass balance: global
(Inventory change, MMbbl/d)
2.0
1.0
0.0
(1.0)
CY12 CY13 CY14 CY15 CY16e CY17e
Gas storage: US Lower 48
(tcf)
6.0
3.0
0.0
Jan 15 Apr 15 Jul 15 Oct 15 Jan 16 Apr 16 Jul 16 Oct 16
5 year min/max
Gas stock
5 year average
Storage forecast
Source: BHP Billiton analysis; US Energy Information Administration (August
2016).
Financial results
16 August 2016
31
bhpbilliton
Iron ore demand outlook remains modest
Chinese and global steel growth to slow
Global steel production is likely to grow modestly in
the future
China’s steel demand growth to become more cyclical as it moves past the inflection point on its intensity curve
As China slows, global steel demand growth will mostly come from emerging economies, primarily India and Southeast Asia
Low-cost iron ore to continue to displace higher cost supply
Supply growth will continue to
outweigh demand growth in coming years
Lower costs through productivity is likely to remain a long-term feature
Pilbara production expected to remain highly cost competitive
Global steel production
break-down
(Regional split %) (CAGR %) 100 10 50 5 0
0
2005
2010
2015
2020e
2025e
2030e
Developed
China
Other EMs¹
CAGR (RHS)
Seaborne iron ore exports by region (% of global market) 60 40 20 0 Australia
Brazil
Others
2010 2015 2030e
Source: Worldsteel; BHP Billiton analysis.
1. Other emerging markets: including developing
Asian countries, Middle East, Africa and Latin America.
Financial results
16
August 2016
32
bhpbilliton
Metallurgical coal outlook supported by growing demand
for high-quality product
Demand improvement to be moderate, supply slowly adjusting
Cost curve has flattened
Lower prices are leading to closures and reduced
investment
The world continues to require steel and metallurgical coal is essential for pig iron production
China expected to continue to import seaborne metallurgical coal – demand supported by coastal market access and requirement for consistent, quality product in larger blast
furnaces – encouraging signs following domestic coal supply reforms
Robust outlook underpinned by scarcity of high-quality resources and demand growth in
emerging economies – particularly in India where we expect strong steel production growth
Seaborne metallurgical coal supply and demand
(Bt)
Supply
opportunity
2015 2020e 2025e 2030e 2035e
Existing supply1 Demand range Demand
Gap to close in emerging market steel stock
(finished steel per capita, t)
15
10
5
0
2000 2015 2020e 2025e 2030e 2035e
Emerging Asia² China US Europe
Source: Wood Mackenzie; Worldsteel; BHP Billiton analysis.
1. Includes
productivity improvements.
2. Emerging Asia includes India, ASEAN and other South Asia. Excludes China, Japan, Taiwan and South Korea.
Financial results
16 August 2016
33
bhpbilliton
Energy coal expected to remain an important part of the
global energy complex
Markets expected to remain oversupplied in the near term
China’s demand for imports is likely to fall further as domestic overcapacity persists, however coal supply reforms encouraging
More supply rationalisation is required to balance the market
Coal’s share of the fuel
mix will decline but total volume will grow due to cost competitiveness in Asia
Absolute demand expected to increase by 10-15% by the mid-2020s, despite a
declining share in the global electricity generation fuel mix
India and South East Asia have 26% of the world’s population, but still account for only 13% of
global electricity generation – low-cost energy coal is expected to be a preferred fuel source
Additional seaborne supply required to meet expected demand
(Bt)
Supply
opportunity
2015 2020e 2025e 2030e 2035e
Existing supply1 Demand range Demand
Global electricity fuel mix2
(PWh) (coal share, %)
50 50
25 25
0 0
2013 2020e 2030e 2035e
Coal
Nuclear
Other
Oil and gas
Hydro
Coal share
Energy coal use in electricity2
(PWh)
15
10
5
0
2013 2020e 2030e 2035e
India China RoW
Other non-OECD Asia
Source: Wood Mackenzie; IEA; BHP Billiton analysis.
1. Includes productivity improvements.
2. Based on IEA data from WEO2015_AnnexA © OECD/IEA, www.iea.org/statistics. Licence: www.iea.org/t&c;
as modified by BHP Billiton.
Financial results
16 August 2016
34
bhpbilliton
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.
| BHP Billiton Limited and BHP Billiton Plc | ||||||
| Date: August 16, 2016 | By: | /s/ Rachel Agnew | ||||
| Name: | Rachel Agnew | |||||
| Title: | Company Secretary | |||||