Wrap Text
Results for the Half Year Ended 31 December 2015
BHP Billiton Plc
Registration number 3196209
Registered in England and Wales
Share code: BIL
ISIN: GB0000566504
23 February 2016
For Announcement to the Market
Name of Companies: BHP Billiton Limited (ABN 49 004 028 077) and
BHP Billiton Plc (Registration No. 3196209)
Report for the half year ended 31 December 2015
This statement includes the consolidated results of the BHP Billiton Group, comprising BHP Billiton Limited and BHP
Billiton Plc, for the half year ended 31 December 2015 compared with the half year ended 31 December 2014 and the
year ended 30 June 2015.
The results are prepared in accordance with IFRS and are presented in US dollars.
Headline Earnings
In accordance with the JSE Listing Requirements, Headline (loss)/earnings is presented below.
Half year Half year Year
ended ended ended
31 December 31 December 30 June
2015 2014 2015
US$M US$M US$M
Restated(1)
(Loss)/earnings attributable to ordinary shareholders(2) (5,669) 4,265 1,910
Adjusted for:
Gain on sale of PP&E, Investments and Operations (23) (34) (9)
Impairments/(reversal of impairments) 7,721 756 3,968
Recycling of re-measurements from equity to the income statement - (1) -
Tax effect of above adjustments (2,420) (232) (1,180)
Net loss on demerger after taxation(3) - - 2,154
Subtotal of Adjustments 5,278 489 4,933
Headline (loss)/earnings (391) 4,754 6,843
Diluted Headline (loss)/earnings (391) 4,754 6,843
Basic earnings per share denominator (millions) 5,322 5,317 5,318
Diluted earnings per share denominator (millions) 5,337 5,334 5,333
Headline (loss)/earnings per share (US cents) (7.4) 89.4 128.7
Diluted Headline (loss)/earnings per share (US cents) (7.3) 89.1 128.3
1) Comparative amounts for the half year ended 31 December 2014 have been restated for the effect of the application of IFRS
5/AASB 5 “Non-current Assets Held for Sale and Discontinued Operations” following the demerger of South32.
2) Includes profit/(loss) after taxation from discontinued operations attributable to ordinary shareholders 31 December 2015 US$
nil (31 December 2014: US$351 million; 30 June 2015 US$(1,573) million).
3) Net loss on demerger after taxation is included in (loss)/profit after taxation from discontinued operations attributable to
ordinary shareholders.
NEWS RELEASE
Release Time IMMEDIATE
Date 23 February 2016
Number 4/16
BHP BILLITON RESULTS FOR THE HALF YEAR ENDED 31 DECEMBER 2015
- The health and safety of our people and the communities in which we operate always come first.
We are committed to addressing the consequences of the tragedy at our joint venture, Samarco.
- Underlying EBITDA(1) of US$6.0 billion and an Underlying EBITDA margin(2) of 40% for the
December 2015 half year, despite significantly weaker commodity prices which had a negative
impact of US$7.8 billion.
- Productivity continues to improve. Black Hawk well costs declined by 30%, Western Australia
Iron Ore and Queensland Coal unit cash costs declined by 25% and 17%, respectively, and
grade-adjusted unit cash costs at Escondida(3) were broadly unchanged.
- Capital and exploration expenditure(4) decreased by 40% to US$3.6 billion. Reflecting the
Group’s rising capital productivity and lower spend in Onshore US, we now expect to invest
US$7.0 billion in the 2016 financial year and US$5.0 billion in the 2017 financial year.
- Robust operating performance, the flexibility of our investment program and a targeted reduction
of working capital supported free cash flow(2) of US$1.2 billion.
- Our strong balance sheet has been maintained, with net debt(2) of US$25.9 billion broadly
unchanged from December 2014 despite weaker prices and significant dividend payments.
- While we were prepared for lower prices across our commodities, we now believe the period of
weaker prices and higher volatility will be prolonged. From a position of strength, we have
adopted a dividend policy that further protects our balance sheet and ensures financial
flexibility.
- The dividend policy provides a minimum 50% payout of Underlying attributable profit at every
reporting period. The Board will assess, every reporting period, the ability to pay amounts
additional to the minimum payment, in accordance with the capital allocation framework.
- The Board has determined to pay an interim dividend of 16 US cents per share which is covered
by free cash flow. This comprises the minimum payout of 4 US cents per share and an additional
amount of 12 US cents per share, reflecting differences between Underlying attributable profit
and free cash flow during the period.
Half year ended 31 December 2015 2014 Change
US$M US$M %
Restated(5)
Statutory
(Loss)/profit from operations (EBIT) (7,030) 7,930 n/a
Attributable (loss)/profit (5,669) 4,265 n/a
Basic (loss)/earnings per share (cents) (106.5) 80.2 n/a
Dividend per share (cents) 16.0 62.0 (74%)
Net operating cash flow 5,260 9,616 (45%)
Continuing operations
Underlying EBITDA(1) 5,994 13,101 (54%)
Underlying EBIT(1) 1,342 8,339 (84%)
Underlying attributable profit(1) 412 4,890 (92%)
Underlying basic earnings per share (cents)(2) 7.7 92.0 (92%)
Capital and exploration expenditure(4) 3,631 6,004 (40%)
Results for the half year ended 31 December 2015
BHP Billiton Chairman, Jac Nasser, said: “Our purpose is to deliver consistent and sustainable shareholder value.
Since the merger of BHP and Billiton in 2001, we have returned a total of US$77 billion in cash to shareholders, more
than any other company in this sector.
“At the same time, BHP Billiton understands the fundamental importance of maintaining a strong balance sheet. The
changes to the dividend policy announced today reflect the Board’s assessment of the outlook for commodities and
the increased financial flexibility this demands. While the continued development of emerging economies will underpin
longer-term demand growth for commodities, we now believe the period of weaker prices and higher volatility will be
prolonged. The adoption of a dividend payout ratio will further support BHP Billiton’s financial strength, while providing
flexibility at the bottom of the cycle and ensuring discipline at the top.
“We have not made these changes lightly. They are a determined response to changing markets that will also help us
take advantage of the significant opportunities ahead. We remain strongly committed to returning cash to our
shareholders and in every reporting period, the Board will assess the possibility of returning additional cash over that
implied by the 50 per cent payout ratio, as we have done this period.”
BHP Billiton Chief Executive Officer, Andrew Mackenzie, said: “Slower growth in China and the disruption of OPEC
have resulted in lower prices than expected. However, our company remains resilient with assets that generate free
cash flow through the cycle and a strong balance sheet.
“Our new dividend policy and transparent capital allocation framework are part of a broader strategy to help BHP
Billiton manage volatility. We have already responded decisively to the changed conditions. The divestment of US$7
billion of assets and the demerger of South32 leaves us with a focused portfolio of large, low-cost, long-life assets in a
set of favoured commodities. We are operating our assets more productively with US$10 billion of gains achieved
since 2012. We expect to realise a further US$2.1 billion of gains in the 2016 financial year, when adjusted for the
impact of lower grades at Escondida. We will also reduce capital expenditure in the 2016 and 2017- financial years by
a total of US$3.5 billion, while retaining a suite of high-return, value-enhancing projects.
“With improved financial flexibility and a portfolio of high-return growth options, we are well positioned to grow
shareholder value and cash returns over the long term.”
In relation to Samarco, he said: “Everyone at BHP Billiton has been deeply affected by the tragedy at Samarco.
Supporting the response efforts, rebuilding communities and restoring the environment impacted by the dam failure
remains a priority and substantial progress has been made. Discussions on an agreement with the authorities for
managing and funding long-term environmental and socio-economic rehabilitation plans are ongoing.”
The health and safety of our people and the communities in which we operate always come first
In the December 2015 half year there were no fatalities at our operated sites and we reported a Total
Recordable Injury Frequency of 4.4 per million hours worked. We continue to focus on managing and
controlling fatal risks and eliminating serious injuries across our business.
Responding to the tragedy following the failure of the Fundão tailings dam at Samarco on 5 November
2015 is a priority for BHP Billiton. Our team in Brazil are focused on doing everything they can to support
the response efforts, repair and maintain existing dams, rebuild communities and restore the environment
impacted by the dam failure. Sadly, authorities have confirmed 17 fatalities, of which five were members of
the community and 12 were people who were working on the dams at the time of the dam failure. In
addition, two people who were working on the dams remain unaccounted for.
All of the families from Bento Rodrigues and Barra Longa affected by the dam failure have been
accommodated in rental housing or relatives’ homes, with the exception of those who preferred to stay in a
hotel. Debit cards have been distributed to those affected in order to provide immediate financial relief.
Samarco and the authorities are continuing to ensure availability of food, water and emergency supplies.
Samarco has also been active in addressing the environmental impact of the dam failure. Such actions
include the construction of dikes to reduce the potential for further tailings inputs to the River Doce,
revegetation measures to reduce erosion and water quality monitoring stations throughout the River Doce
system. Samarco has engaged world-class consulting specialists in engineering, social and environmental
sciences and environmental emergencies, to develop the environmental and social rehabilitation actions in
all areas impacted along the River Doce.
BHP Billiton, Vale and Samarco have jointly commissioned an external investigation into the cause of the
dam failure. BHP Billiton has committed to publicly release the findings of the investigation, and to sharing
the results with other resources companies. Discussions with the national government of Brazil and the
state governments of Minas Gerais and Espírito Santo, aimed at reaching agreement for managing and
funding long-term environmental and socio-economic rehabilitation plans, are ongoing.
Asset quality and robust operating performance provide resilience in a challenging environment
BHP Billiton delivered Underlying EBITDA of US$6.0 billion and an Underlying EBITDA margin of 40 per
cent in the December 2015 half year, despite significantly weaker prices across all our major commodities
which had a negative impact of US$7.8 billion.
An unfavourable change in productivity of US$169 million(6) was recorded in the period due to the
expected 25 per cent grade decline at Escondida. Excluding this impact, productivity increased by US$472
million. Further improvements continue to be realised across the portfolio and we expect to deliver
approximately US$600 million of productivity gains in the 2016 financial year. Excluding the impact of grade
decline at Escondida, we expect gains of approximately US$2.1 billion.
During the period, Black Hawk drilling costs per well declined by 30 per cent, and Western Australia Iron
Ore (WAIO) and Queensland Coal unit cash costs declined by 25 per cent and 17 per cent, respectively.
Grade-adjusted unit cash costs at Escondida remained broadly unchanged despite reduced recoveries
from the processing of lower-grade inventory, the commissioning of the OGP1 concentrator and additional
stacking of lower-grade material to sulphide heap leach. The inventory was drawn down to maximise cash
flow and combined with other working capital initiatives, facilitated a substantial increase in cash flow.
These factors offset a 12 per cent improvement in underlying net cash costs(7).
As our focus on safe productivity continues we have maintained or lowered unit cost guidance at our major
assets. Historical costs and guidance for the 2016 financial year are summarised in the following table:
FY15 H1 FY16 Previous Current FY16e vs
FY16(i) FY16(i) FY15
guidance guidance
Black Hawk drilling cost per well (US$ million) 3.4 2.6 2.5 2.3 (32%)
Escondida unit cost (US$ per pound)(ii) 1.01 1.45 1.21 1.21 20%
Escondida grade-adjusted unit cost (US$ per pound)(ii) 1.01 1.02 0.87 0.87 (14%)
Western Australia Iron Ore unit cost (US$ per tonne) 19 15 15 15 (20%)
Queensland Coal unit cost (US$ per tonne) 65 59 61 59 (9%)
(i) Current 2016 financial year guidance is based on exchange rates of AUD/USD 0.72 and USD/CLP 702. Previous guidance
was based on exchange rates of AUD/USD 0.74 and USD/CLP 702.
(ii) Previous guidance presented at the Copper briefing and site tour in December 2015. Grade-adjusted unit cost guidance is
presented on a grade-equivalent basis relative to the 2015 financial year. Grades are expected to decline by 27 per cent in the
2016 financial year.
The Group reported Underlying attributable profit of US$412 million, while the Attributable loss of US$5.7
billion includes US$6.1 billion of exceptional items (after tax) related to: an impairment charge of US$4.9
billion against the carrying value of the Onshore US assets; US$858 million for the financial impacts of the
Samarco dam failure on the Group’s income statement; and US$390 million for global taxation matters.
Capital and exploration expenditure declined to US$3.6 billion, down 40 per cent, as we continued to
exercise the flexibility in our investment program in response to market conditions. Other factors include
improved capital productivity and the benefits of a stronger US dollar. Combined with a robust operating
performance and a targeted reduction of working capital, the Group delivered free cash flow of US$1.2
billion during the period.
Despite the significant weakening of commodity prices, we maintained our strong balance sheet, finishing
the period with net debt of US$25.9 billion (30 June 2015: US$24.4 billion; 31 December 2014: US$24.9
billion) and a gearing ratio(2) of 29.7 per cent (30 June 2015: 25.7 per cent; 31 December 2014: 22.4 per
cent).
Enhancing our capital allocation framework to maximise shareholder value
Since the merger of BHP and Billiton in 2001, our capital management framework has served our
shareholders well. We maintained a strong balance sheet and returned US$77 billion in dividends and buy-
backs to shareholders. In response to the increase in demand over the period, we invested in our tier 1
assets and infrastructure, doubling volumes and providing valuable options for future development. As a
low-cost producer, this was the value-maximising strategy which underpinned superior margins and
substantial cash flow generation.
Several years ago, in anticipation of slowing demand growth and the abundance of potential new low-cost
supply, we shifted our focus to reducing costs and debottlenecking our operations. Since 2012, we have
embedded annualised productivity gains of more than US$10 billion(6) and reduced capital and exploration
expenditure by over 50 per cent. Through the divestment of US$7 billion of assets and the demerger of
South32, we have focused our portfolio on a small group of large, low-cost, long-life assets.
While we were prepared for lower prices across our commodities, the reduction over the last six months
has been more severe and synchronised than expected. The short to medium-term outlook for the sector
remains challenging. We expect prices will take time to recover and are likely to remain volatile, however
this environment should provide opportunities. We enter this downturn from a position of strength, with the
simplest portfolio of high-quality assets, sector-leading operating capabilities, rising capital flexibility as
current projects are completed and a strong balance sheet.
Our strong balance sheet remains a fundamental enabler of our strategy. It provides access to sufficient,
low-cost funding at all points in the cycle which provides optionality and insulates our operations from rising
volatility. Our strength is demonstrated by our solid cash flow to net debt metrics (reflected in our credit
ratings), liquidity of US$17 billion, moderate gearing and long-dated debt maturity profile.
Today, we continue to implement measures to both preserve the Group’s balance sheet strength and align
our capital allocation framework with the cyclical nature of the industry. Our priorities for capital are to:
• first, maintain safe and stable operations;
• second, maintain a strong balance sheet through the cycle;
• third, pay shareholders a minimum of 50 per cent of Underlying attributable profit as dividends; and
• fourth, direct remaining cash to the value-maximising outcome, with debt reduction, investing in
growth projects, buying back shares, paying additional dividends and acquiring assets, all
competing for capital.
This framework provides valuable flexibility. This flexibility will support greater value creation for
shareholders as it enhances our ability to maintain a strong balance sheet and invest counter cyclically at
the bottom of the cycle, and embeds increased cash returns to shareholders at the top.
The adoption of a 50 per cent dividend payout ratio will re-phase distributions to shareholders and while
this payout level is in line with the average cash returned to shareholders since the merger, dividends will
be more closely linked to the performance of our business. We remain strongly committed to cash returns
to shareholders. At every reporting period, the Board will consider cash returns in excess of the minimum
implied by the payout ratio, in accordance with the framework outlined above.
Today, the Board has determined to pay an interim dividend of 16 US cents per share, a level covered by
the Group’s free cash flow. This comprises the minimum payout of four US cents per share and an
additional amount of 12 US cents per share, reflecting differences between Underlying attributable profit
and free cash flow during the period.
Strongly positioned for the future
The Group’s rising capital productivity and latent capacity opportunities, cost deflation and a stronger US
dollar mean that we do not require the same level of investment to grow as in the past. Reflecting this, and
the flexibility of our Onshore US investment plans, we now expect our capital and exploration expenditure
to be US$7.0 billion in the 2016 financial year and US$5.0 billion in the 2017 financial year. While this
represents a total reduction of US$3.5 billion from previous guidance, the only reduction in activity is at
Onshore US where we continue to respond to current market conditions.
Our most valuable growth will come from operating more efficiently. This will be supported in the short to
medium term by the release of latent capacity across the portfolio which should deliver growth in volumes
and free cash flow at low capital intensity. In the medium to long term, we have a portfolio of development
options which we can execute when the timing is right and it is determined to be the value-maximising
outcome.
We offer a unique proposition within the sector. We believe we have:
• the simplest portfolio of large, low-cost, long-life assets diversified across a set of favoured
commodities;
• sector-leading operating capabilities;
• the sector’s strongest balance sheet, supported at all points in the cycle by a more flexible dividend
and investment program;
• a portfolio of value-enhancing growth options; and
• a transparent capital allocation framework to direct excess cash to the value-maximising outcome.
While the sector faces challenges in the short to medium term, we remain confident in the long-term
outlook which is supported by the ongoing urbanisation and industrialisation of emerging economies
coupled with growing supply-side challenges, particularly in copper and oil. With rising volatility, the
strength of our unique portfolio positions us to take advantage of market conditions through the cycle.
Outlook
Economic outlook
Global growth is expected to pick up slightly in the 2016 calendar year but will remain modest and subject
to ongoing financial markets volatility. Major developed economies should continue to recover mildly while
emerging markets will see divergent levels of growth. Solid growth in India and parts of emerging Asia and
Europe will be partially offset by ongoing weakness in Latin America and Russia.
China will experience slower overall growth, and the divergence in sectoral performance is expected to
persist with relatively soft industrial activity offset by a solid contribution from the services sector. This
pattern reflects what appears to be a faster than expected transition away from reliance on investment,
particularly in heavy industry, which is constraining commodity demand growth in the near term. Volatility
will continue in the short-term as cautious economic reform evolves, particularly in the financial sector. With
Chinese authorities appearing to increase their focus on “supply-side reform”, including State-Owned
Enterprises, we expect some capacity reduction as industry consolidates over time. Over the longer term,
economic reform and ongoing urbanisation will help to offset the impact of a declining workforce as growth
converges to levels similar to developed economies.
The US economy should see a mild lift in growth driven by consumer demand, supported by low energy
prices and an improving housing market. The extent of interest rate increases in the United States in the
2016 calendar year will depend on the pace of economic growth and inflation. The Eurozone will likely see
modest growth continue, supported by a lower Euro and stimulatory monetary policy. In Japan, better
wages growth, increased business investment and a lower Yen should support mild economic
improvement, though growth remains fragile. India’s economy will continue to grow solidly supported by
infrastructure spend and lower commodity prices. In the longer term, growth will be sustained by rising
domestic consumption and successful reform.
Commodities outlook
The crude oil price fell significantly in the first half of the 2016 financial year as supply continued to outpace
demand following the disruption of OPEC and stronger than anticipated non-OPEC production. In the short
term, we expect prices to remain weak as high inventory levels weigh on an oversupplied market and rising
OPEC exports offset production declines in the United States. We expect the market will then rebalance as
declining investment leads to a slowdown in non-OPEC supply growth while increasing demand draws
down stocks. The long-term outlook remains healthy and is underpinned by rising transport sector demand
in developing countries, natural field decline and deferrals of investment.
The domestic gas price in the United States declined due to the ongoing over-supply and mild early-winter
weather. Despite strong demand growth from the power sector, high gas storage levels are likely to keep
prices subdued in the short term. In the longer term, demand is expected to benefit from LNG exports,
further growth in gas power generation and increasing industrial use. As core gas reserves are depleted,
less productive and higher-cost shale areas will be required to meet growing demand, supporting prices. In
LNG, weaker fundamentals and low oil prices have impacted the spot market while longer-run demand
growth remains healthy.
Copper prices continued to be affected by growing supply, slightly weaker than expected demand,
improved productivity at existing operations and a stronger US dollar. In the short to medium term, new and
expanded production is expected to keep the market well supplied, despite cuts being announced to
higher-cost production. In the long term, the copper outlook remains positive as demand is supported by
China’s shift towards consumption and the scope for substantial growth in emerging markets. A deficit is
expected to emerge towards the end of this decade as grade decline, rising costs and limited high-quality
development opportunities constrain the industry’s ability to meet growing demand.
Our outlook for Chinese crude steel production remains unchanged, peaking between 935 Mt and 985 Mt in
the middle of the next decade, as China continues to urbanise and mature its manufacturing capability. In
the short term, Chinese steel demand is expected to remain soft, with modest potential improvement if
construction and infrastructure activity ramp-up in the first half of the 2016 calendar year. The iron ore price
will likely remain low, constrained by weak demand and abundant seaborne iron ore supply. Over time,
additional low-cost seaborne supply will continue to displace higher-cost supply, and we expect productivity
gains will continue to be an industry feature. These factors point to a prolonged period of market
rebalancing.
In metallurgical coal, industry-wide supplier cost compression is expected to persist through the 2016
calendar year, with recent devaluations in China’s currency highlighting a key uncertainty for seaborne
demand as imports become relatively more expensive. While high-cost seaborne supply will continue to
rationalise, we expect further growth in low-cost, premium hard coking coal supply to offset production cuts
and constrain potential for near-term price recovery. In the long term, we expect emerging markets such as
India to support seaborne demand growth, while high-quality metallurgical coals will continue to offer steel
makers value-in-use benefits to their operations.
Projects
Historical capital and exploration expenditure and guidance for the 2016 and 2017 financial years are
summarised in the following table:
FY17e FY16e H1 FY16 H1 FY15 FY15
US$B US$B US$M US$M US$M
Capital expenditure (purchases of property, plant and 5.0 7.6 3,958 6,361 11,947
equipment)
Add: exploration expenditure 0.7 0.7 410 409 816
Capital and exploration expenditure (cash basis) 5.7 8.3 4,368 6,770 12,763
Add: equity accounted investments 0.2 0.2 160 340 434
Less: capitalised deferred stripping(i) (0.4) (0.7) (391) (459) (815)
Less: non-controlling interests (0.5) (0.8) (506) (647) (1,342)
Capital and exploration expenditure (BHP Billiton share) 5.0 7.0 3,631 6,004 11,040
– continuing operations
(i) Capitalised deferred stripping includes US$90 million attributable to non-controlling interests for 31 December 2015 (31
December 2014: US$88 million).
During the December 2015 half year, BHP Billiton approved an investment of US$314 million (BHP Billiton
share) for the North West Shelf Greater Western Flank-B petroleum project. This follows the delivery of first
production from the North West Shelf Greater Western Flank-A project during the period. At the end of the
period, BHP Billiton had four major projects in progress with a combined budget of US$6.9 billion over the
life of the projects.
Business Project and Capacity(i) Capital Date of initial Progress
ownership expenditure production
(i) US$M
Budget Actual Target
Projects which delivered first production during the December
2015 half year
Petroleum North West Shelf To maintain LNG plant 400 Q4 CY15 CY16 First production
Greater Western throughput from the North West achieved
Flank-A Shelf operations.
(Australia)
16.67%
(non-operator)
Projects in execution at 31 December 2015
Petroleum Bass Strait Longford Designed to process 520 CY16 76% complete
Gas approximately 400 MMcf/d of
Conditioning high CO2 gas.
Plant (Australia)
50% (non-operator)
Petroleum North West Shelf To maintain LNG plant 314 CY19 Approved by joint
Greater Western throughput from the North West venture partners in
Flank-B (Australia) Shelf operations. December 2015
16.67%
(non-operator)
Copper Escondida Water New desalination facility to 3,430 CY17 76% complete
Supply (Chile) ensure continued water supply
57.5% to Escondida.
Other projects in progress at 31 December 2015
Potash(ii) Jansen Potash Investment to finish the 2,600 54% complete
(Canada) excavation and lining of the
100% production and service shafts,
and to continue the installation
of essential surface
infrastructure and utilities.
(i) Unless noted otherwise, references to capacity are on a 100 per cent basis, references to capital expenditure from subsidiaries
are reported on a 100 per cent basis and references to capital expenditure from joint operations are reported on a
proportionate consolidation basis.
(ii) Excavation and lining of the Jansen project shafts is steadily progressing. Total potash expenditure of approximately US$350
million, including capital expenditure of approximately US$180 million, is expected for the 2016 financial year.
Income statement
To provide clarity into the underlying performance of our operations, Underlying attributable profit and
Underlying EBIT are set out in the following tables:
Half year ended 31 December 2015 2014
US$M US$M
Underlying attributable profit 412 4,890
Attributable profit – discontinued operations – 351
Exceptional items (after taxation) – refer to pages 10 and 39 (6,132) (988)
Minority interest in exceptional items 51 12
Attributable (loss)/profit (5,669) 4,265
Half year ended 31 December 2015 2014
US$M US$M
Underlying EBIT 1,342 8,339
Exceptional items (before taxation) – refer to pages 10 and 39 (8,372) (409)
(Loss)/profit from operations 7,030 7,930
Underlying EBIT
The following table and commentary describes the impact of the principal factors that affected Underlying
EBIT for the December 2015 half year compared with the December 2014 half year:
US$M
Half year ended 31 December 2014 8,339
Net price impact:
Change in sales prices (8,235) Lower average realised prices for all our major commodities.
Price-linked costs 469 Reduced royalties reflect lower realised prices.
(7,766)
Change in volumes:
Productivity (167) Productivity improvements across WAIO’s integrated supply
chain were more than offset by lower volumes at Escondida
due to expected grade decline.
Growth (58) Lower gas volumes reflect the deferral of development
activity in Onshore US.
(225)
Change in controllable cash costs:
Operating cash costs (48) Lower costs in Petroleum, Iron Ore and Coal were more
than offset by the impact of the drawdown of lower-grade
inventory and grade decline at Escondida.
Exploration and business development 198 Reduction in Petroleum exploration expense.
150
Change in other costs:
1,025 Impact of the stronger US dollar against the Australian dollar
Exchange rates and Chilean peso.
Inflation (160) Impact of inflation on the Group’s cost base.
Fuel and energy 209 Lower diesel prices across all minerals businesses.
Depreciation, deferred stripping and 9 Lower impairment charges in Petroleum offset higher
impairment (8) depreciation across the Group.
One-off items (118) Reflects royalty and taxation matters.
965
Asset sales (31) Loss on disposal of equipment following closure of the
Crinum coal mine.
Ceased and sold operations (15) Cessation of petroleum production at Stybarrow on 30 June
2015.
Other items (75) Lower average realised prices received by our equity
accounted investments.
Half year ended 31 December 2015 1,342
The following table reconciles relevant factors with changes in the Group’s productivity:
Half year ended 31 December 2015 US$M
Change in controllable cash costs 150
Change in volumes attributed to productivity (167)
Change in productivity in Underlying EBIT (17)
Change in capitalised exploration (152)
Change attributable to productivity initiatives (169)
Escondida grade impact 641
Change attributable to productivity initiatives excluding Escondida grade impact 472
Prices and exchange rates
The average realised prices achieved for our major commodities are summarised in the following table:
H1 FY16 H1 FY16 H1 FY16
vs vs vs
Average realised prices(i) H1 FY16 H1 FY15 H2 FY15 FY15 H1 FY15 H2 FY15 FY15
Oil (crude and condensate) (US$/bbl) 42 85 52 68 (51%) (19%) (38%)
Natural gas (US$/Mscf)(ii) 2.91 4.21 3.29 3.77 (31%) (12%) (23%)
US natural gas (US$/Mscf) 2.35 3.89 2.59 3.27 (40%) (9%) (28%)
LNG (US$/Mscf) 8.24 13.76 9.40 11.65 (40%) (12%) (29%)
Copper (US$/lb)(iii) 2.12 2.98 2.61 2.78 (29%) (19%) (24%)
Iron ore (US$/wmt, FOB) 43 70 53 61 (39%) (19%) (30%)
Hard coking coal (US$/t) 82 110 99 105 (25%) (17%) (22%)
Weak coking coal (US$/t) 67 92 85 88 (27%) (21%) (24%)
Thermal coal (US$/t)(iv) 49 61 56 58 (20%) (13%) (16%)
Nickel metal (US$/t) 9,926 16,905 13,688 15,301 (41%) (27%) (35%)
(i) 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.
(ii) Includes internal sales.
(iii)Includes the impact of provisional pricing and finalisation adjustments which decreased EBIT by US$336 million in the
December 2015 half year.
(iv) Export sales only; excludes Cerrejón. Includes thermal coal sales from metallurgical coal mines.
The following exchange rates relative to the US dollar have been applied in the financial information:
Average Average
Half year ended Half year ended As at As at As at
31 December 31 December 31 December 31 December 30 June
Currency 2015 2014 2015 2014 2015
Australian dollar(i) 0.72 0.89 0.73 0.82 0.77
Chilean peso 687 587 707 607 635
(i) Displayed as US$ to A$1 based on common convention.
Net finance costs
Net finance costs increased by US$195 million to US$429 million. This reflected higher benchmark interest
rates and the issue of multi-currency hybrid notes during the December 2015 half year, and the gain on the
early redemption of the Petrohawk Energy Corporation Senior Notes in the prior period.
Taxation expense
The Group’s adjusted effective tax rate(2), which excludes the influence of exchange rate movements and
exceptional items, was 33.5 per cent (31 December 2014: 32.0 per cent).
Half year ended 31 December 2015 2014
(Loss)/profit Income tax % Profit Income %
before benefit/(expense) before tax
taxation US$M taxation expense
US$M US$M US$M
Statutory effective tax rate (7,459) 1,726 – 7,696 (3,304) 42.9%
Adjusted for:
Exchange rate movements – 208 – 129
Exceptional items 8,372 (2,240) 409 579
Adjusted effective tax rate 913 (306) 33.5% 8,105 (2,596) 32.0%
Other royalty and excise arrangements which are not profit based are recognised as operating costs within
(Loss)/profit before taxation. These amounted to US$755 million during the period (31 December 2014:
US$962 million).
Exceptional items
The following table sets out the exceptional items in the December 2015 half year. Additional commentary
is included on page 39.
Half year ended 31 December 2015 Gross Tax Net
US$M US$M US$M
Exceptional items by category
Samarco dam failure(i) (1,188) 330 (858)
Impairment of Onshore US assets(ii) (7,184) 2,300 (4,884)
Global taxation matters – (390) (390)
Total (8,372) 2,240 (6,132)
(i) Comprises the following: US$(655) million for the share of loss relating to the Samarco dam failure; US$(525) million for the
impairment of the carrying value of the investment in Samarco; US$(8) million for the costs incurred directly by BHP Billiton in
relation to the Samarco dam failure. Refer to note 9 Significant events of the Financial Report for information regarding the
financial impact of the Samarco dam failure in November 2015 on BHP Billiton’s share of Samarco’s operating profit.
(ii) Includes amounts attributable to non-controlling interests of US$(51) million after tax benefit.
Dividend
Our Board today determined to pay an interim dividend of 16 US cents per share. The interim dividend to
be paid by BHP Billiton Limited will be fully franked for Australian taxation purposes.
Events in respect of the interim dividend Date
Last day to trade cum dividend on JSE Limited (JSE) and currency conversion into rand 4 March 2016
Ex-dividend Date JSE 7 March 2016
Ex-dividend Date New York Stock Exchange (NYSE) 9 March 2016
Ex-dividend Date Australian Securities Exchange (ASX)(i) and London Stock Exchange (LSE) 10 March 2016
Record Date (including currency conversion and currency election dates for ASX and LSE) 11 March 2016
Payment Date 31 March 2016
(i) The ASX has confirmed it will implement a T+2 settlement cycle with a transition date of 7 March 2016. A T+2 settlement cycle
will change the previously announced ASX ex-dividend date for the interim dividend from 9 March 2016 to 10 March 2016.
BHP Billiton Plc shareholders registered on the South African section of the register will not be able to
dematerialise or rematerialise their shareholdings between the dates of 7 and 11 March 2016 (inclusive),
nor will transfers between the UK register and the South African register be permitted between the dates of
4 and 11 March 2016 (inclusive). American Depositary Shares (ADSs) each represent two fully paid
ordinary shares and receive dividends accordingly.
Details of the currency exchange rates applicable for the dividend will be announced to the relevant stock
exchanges following conversion and will appear on the Group’s website.
Debt management and liquidity
During the December 2015 half year, the Group issued US$3.25 billion of subordinated fixed rate reset
notes in the US Dollar market across two tranches, EUR2.0 billion of subordinated fixed rate reset notes in
the Euro market across two tranches and GBP600 million of subordinated fixed rate reset notes in the
Sterling market.
The issuance of these hybrid notes comprised the following:
Currency Size (M) Coupon Paid
Subordinated Non-Call 5 Fixed Rate Reset Notes due 2075 (60NC5) US$ 1,000 6.250% semi-
annually
Subordinated Non-Call 10 Fixed Rate Reset Notes due 2075 US$ 2,250 6.750% semi-
(60NC10) annually
Subordinated Non-Call 5.5 Fixed Rate Reset Notes due 2076 EUR 1,250 4.750% annually
(60.5NC5.5)
Subordinated Non-Call 9 Fixed Rate Reset Notes due 2079 (64NC9) EUR 750 5.625% annually
Subordinated Non-Call 7 Fixed Rate Reset Notes due 2077 (62NC7) GBP 600 6.500% annually
The Group has a US$6.0 billion commercial paper program backed by a US$6.0 billion revolving credit
facility. The facility expires in May 2020 and has a one-year extension option. As at 31 December 2015, the
Group had US$ nil outstanding in the US commercial paper market and the Group’s cash and cash
equivalents on hand were US$10.6 billion.
Corporate governance
On 3 February 2016, Anita Frew was appointed as a member of the Risk and Audit Committee.
The current members of the Board’s Committees are:
Risk and Audit Nomination and Remuneration Sustainability
Committee Governance Committee Committee Committee
Lindsay Maxsted (Chair) Jac Nasser (Chair) Carolyn Hewson (Chair) John Schubert (Chair)
Malcolm Broomhead John Schubert Pat Davies Malcolm Broomhead
Wayne Murdy Shriti Vadera Shriti Vadera Malcolm Brinded
Anita Frew Pat Davies
Business summary(i)
A summary of the performance of the Businesses for the December 2015 and December 2014 half years is
presented below.
Half year ended Loss from Net
31 December 2015 Revenue Underlying Underlying Exceptional operations operating Capital Exploration Exploration to
US$M (ii) EBITDA EBIT items (EBIT) assets expenditure gross(iii) profit(iv)
Petroleum 3,800 2,215 (199) (7,184) (7,383) 25,950 1,455 321 126
Copper 3,893 829 101 - 101 23,636 1,596 33 33
Iron Ore 5,349 2,823 1,927 (1,180) 747 22,264 553 46 30
Coal 2,337 155 (342) - (342) 11,225 185 9 9
Group and unallocated items(v) 404 (28) (145) (8) (153) 3,038 169 1 1
Inter-segment adjustment (71) - - - - - - - -
BHP Billiton Group 15,712 5,994 1,342 (8,372) (7,030) 86,113 3,958 410 199
Half year ended
31 December 2014 Profit from Net
(Restated) Revenue Underlying Underlying Exceptional operations operating Capital Exploration Exploration to
US$M (ii) EBITDA EBIT items (EBIT) assets expenditure gross(iii) profit(iv)
Petroleum 6,936 4,868 2,256 - 2,256 36,482 2,604 268 256
Copper 5,781 2,821 2,046 - 2,046 23,035 1,897 41 41
Iron Ore 8,418 4,992 4,200 - 4,200 24,433 1,104 71 16
Coal 3,143 558 139 - 139 12,241 478 12 12
Group and unallocated items(v) 820 (138) (302) (409) (711) 3,352 278 17 17
Inter-segment adjustment (238) - - - - - - - -
BHP Billiton Group 24,860 13,101 8,339 (409) 7,930 99,543 6,361 409 342
(i) Group and business level information is reported on a statutory basis which, in relation to Underlying EBIT, includes net finance
costs and taxation expense of US$119 million (2014: US$270 million) related to equity accounted investments. It excludes
exceptional items of US$655 million (2014: US$ nil) related to equity accounted investments.
(ii) Revenue is based on Group realised prices and includes third party products. Sale of third party products by the Group
contributed revenue of US$555 million and Underlying EBIT of (US$27) million (2014: US$630 million and US$1 million).
(iii) Includes US$211 million capitalised exploration (2014: US$59 million).
(iv) Includes US$ nil of exploration expenditure previously capitalised, written off as impaired (included in depreciation and
amortisation) (2014: a net reversal of US$8 million exploration expenditure previously capitalised, written off as impaired).
(v) Comprises Group Functions, other unallocated operations including Potash (previously disclosed in the former Petroleum and
Potash business) and Nickel West, consolidation adjustments and external sales of freight and fuel to third parties.
Half year ended Net
31 December 2015 Underlying Underlying operating Capital Exploration Exploration
US$M Revenue EBITDA D&A EBIT assets expenditure gross to profit
Potash - (84) 3 (87) 2,775 113 - -
Nickel West 387 (109) 33 (142) (123) 49 1 1
Half year ended Net
31 December 2014 Underlying Underlying operating Capital Exploration Exploration
US$M Revenue EBITDA D&A EBIT assets expenditure gross to profit
Potash - (109) 3 (112) 2,507 221 1 1
Nickel West 792 71 65 6 80 55 16 16
Petroleum
Underlying EBIT for Petroleum decreased by US$2.5 billion to US$(235) million in the December 2015 half
year.
US$M
Underlying EBIT for the half year ended 31 December 2014(i) 2,237
Net price impact(ii) (2,780)
Change in volumes: growth (58)
Change in controllable cash costs 222
Change in other costs:
Depreciation, deferred stripping and impairment 96
Other(iii) 48
Underlying EBIT for the half year ended 31 December 2015(i) (235)
(i) Excludes closed mines.
(ii) Average realised price: crude and condensate oil US$42/bbl (2014: US$85/bbl); natural gas US$2.91/Mscf (2014:
US$4.21/Mscf); LNG US$8.24/Mscf (2014: US$13.76/Mscf).
(iii)Other includes: exchange rates; inflation; asset sales; ceased and sold operations; other items. Other items includes Onshore
US rig termination charges of US$65 million (2014: US$13 million).
Total petroleum production for the December 2015 half year decreased by five per cent to 124.7 MMboe.
• Liquids production decreased by three per cent to 60.5 MMboe as higher Onshore US liquids
volumes were more than offset by lower Conventional liquids production due to industrial action at
Bass Strait and natural field decline across the portfolio.
• Natural gas production declined by seven per cent to 386 bcf as lower Onshore US gas volumes
were partially offset by higher seasonal demand at Bass Strait.
Total petroleum production guidance for the 2016 financial year remains unchanged at 237 MMboe.
• Strong performance by our Conventional business is expected to offset lower Onshore US volumes
following a further reduction in development activity, a third party gas plant outage in the Permian
and the successful divestment of our gas business in Pakistan.
Depreciation and impairment charges, excluding exceptional items, declined in the December 2015 half
year as a result of US$328 million of impairment charges incurred in the previous period. This was partially
offset by US$210 million of higher depreciation and amortisation charges in Onshore US due to a reduction
in total reserves, primarily at Fayetteville and Hawkville due to acreage relinquishments and amended
development plans. Depreciation and amortisation charges are expected to decline by approximately
US$450 million in the second half of the 2016 financial year following an impairment charge of US$7.2
billion against the carrying value of the Onshore US assets in the December 2015 half year.
Petroleum capital expenditure declined by 44 per cent to US$1.5 billion in the December 2015 half year.
This included US$851 million of Onshore US drilling and development expenditure. We realised further
improvements in shale drilling and completions efficiency during the period as our drill time and completion
techniques showed marked improvement in the Black Hawk and Permian. We now expect to reduce Black
Hawk drilling costs further to US$2.3 million per well in the 2016 financial year.
Cost per well (US$M) H1 FY16 H2 FY15 H1 FY15 FY15
Black Hawk: Drilling cost 2.6 2.9 3.7 3.4
Black Hawk: Completion cost 3.2 4.2 5.4 4.9
Permian: Drilling cost 3.9 4.3 4.8 4.6
Permian: Completion cost 3.1 4.3 4.9 4.6
Petroleum capital expenditure of approximately US$2.7 billion is now planned in the 2016 financial year, a
seven per cent decline from prior guidance of US$2.9 billion. This includes Conventional capital
expenditure of US$1.4 billion, which remains focused on high-return infill drilling opportunities in the Gulf of
Mexico and life extension projects at Bass Strait and North West Shelf, and Onshore US capital
expenditure of US$1.3 billion, of which approximately US$200 million relates to a reduction in capital
creditors.
Our Onshore US operated rig count has now reduced from seven to five as we defer development activity
to preserve value. Completions activity will continue to be tailored to market conditions and we will exercise
further flexibility should there be greater value in deferral. We have continued confidence in the quality of
our Onshore US acreage, and our track record in operating performance and capital productivity is among
the best in the industry. While we are focused on value and cash flow preservation as we manage through
this period of lower prices, we retain the option to develop our resources as prices recover to maximise the
value of these quality assets.
December 2015 half year Liquids focused areas Gas focused areas
(December 2014 half year) Eagle Ford Permian Haynesville Fayetteville Total
Capital expenditure(i) US$ billion 0.6 (1.2) 0.2 (0.4) 0.0 (0.2) 0.0 (0.1) 0.9 (1.9)
Rig allocation At period end 5 (18) 2 (5) 0 (3) 0 (0) 7 (26)
Net wells drilled and completed 74 (85) 19 (18) 4 (13) 10 (8) 107 (124)
(ii) Period total
Net productive wells At period end 912 (732) 94 (49) 409 (406) 1,085 (1,021) 2,500 (2,208)
(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.
Petroleum exploration expenditure for the December 2015 half year was US$321 million, of which US$126
million was expensed. Activity for the period was largely focused in the deepwater Gulf of Mexico, the
Caribbean and the Beagle sub-basin off the coast of Western Australia. We are pursuing high-quality oil
plays in these three focus areas and continue to invest opportunistically in future growth options. Since
August 2015, BHP Billiton has acquired 26 blocks in the Western Gulf of Mexico Lease Sale with a 100 per
cent working interest. A US$600 million exploration program remains on plan for the 2016 financial year,
largely focused on acreage access, seismic data acquisition and increased activity in our exploration drilling
program.
Financial information for the Petroleum business for the December 2015 and December 2014 half years is
presented below.
Half year ended Net
31 December 2015 Revenue Underlying Underlying operating Capital Exploration Exploration to
US$M (i) EBITDA D&A EBIT assets expenditure gross(ii) profit(iii)
Australia Production Unit(iv) 374 299 174 125 1,349 132
Bass Strait 454 328 74 254 3,052 134
North West Shelf 653 478 102 376 1,386 75
Atlantis 347 249 238 11 2,039 133
Shenzi 282 237 128 109 1,190 59
Mad Dog 52 41 14 27 635 61
Eagle Ford(v) 884 440 1,079 (639) 7,574 586
Permian(v) 140 23 140 (117) 1,110 201
Haynesville(v) 170 (11) 204 (215) 3,158 26
Fayetteville(v) 140 23 125 (102) 962 38
Trinidad/Tobago(iv) 71 153 11 142 884 5
Algeria 73 52 17 35 81 10
Exploration - (126) 43 (169) 897 -
Other(vi)(vii)(viii) 79 (9) 67 (76) 2,495 (5)
Total Petroleum from Group
production 3,719 2,177 2,416 (239) 26,812 1,455 321 126
Closed mines(ix) - 36 - 36 (862) - - -
Third party products 88 4 - 4 - -
Total Petroleum 3,807 2,217 2,416 (199) 25,950 1,455 321 126
Adjustment for equity accounted
investments(x) (7) (2) (2) - - - - -
Total Petroleum statutory result 3,800 2,215 2,414 (199) 25,950 1,455 321 126
Half year ended
31 December 2014 Net
(Restated) Revenue Underlying Underlying operating Capital Exploration Exploration to
US$M (i) EBITDA D&A EBIT assets expenditure gross(ii) profit(iii)
Australia Production Unit(iv) 603 539 182 357 1,348 18
Bass Strait 860 719 72 647 3,040 191
North West Shelf 1,157 860 101 759 1,892 71
Atlantis 701 641 192 449 2,196 174
Shenzi 611 555 147 408 1,435 97
Mad Dog 105 51 15 36 578 48
Onshore US(v)(xi) 2,380 1,385 1,747 (362) 22,803 1,923
Trinidad/Tobago(iv)(viii) 103 81 14 67 765 (8)
Algeria 203 171 19 152 106 11
Exploration - (244) 43 (287) 531 -
Other(vi)(vii) 177 93 82 11 2,790 79
Total Petroleum from Group
production 6,900 4,851 2,614 2,237 37,484 2,604 268 256
Closed mines(ix) - 19 - 19 (1,002) - - -
Third party products 44 - - - - -
Total Petroleum 6,944 4,870 2,614 2,256 36,482 2,604 268 256
Adjustment for equity accounted
investments(x) (8) (2) (2) - - - - -
Total Petroleum statutory result 6,936 4,868 2,612 2,256 36,482 2,604 268 256
(i) Petroleum revenue from Group production includes: crude oil US$2,003 million (2014: US$4,001 million), natural gas US$933
million (2014: US$1,439 million), LNG US$481 million (2014: US$833 million), NGL US$206 million (2014: US$429 million) and
other US$89 million (2014: US$190 million).
(ii) Includes US$195 million of capitalised exploration (2014: US$24 million).
(iii) Includes US$ nil of exploration expenditure previously capitalised, written off as impaired (included in depreciation and
amortisation) (2014: US$12 million).
(iv) Australia Production Unit includes Macedon, Pyrenees, Minerva and Stybarrow. Comparative period has been restated to
report Australia Production Unit and Trinidad/Tobago separately from Other.
(v) Onshore US is now reported separately between Eagle Ford, Permian, Haynesville and Fayetteville.
(vi) Predominantly divisional activities, business development, Pakistan, UK, Neptune, Genesis and ceased and sold operations.
Also includes the Caesar oil pipeline and the Cleopatra gas pipeline which are equity accounted investments and are reported
on a proportionate consolidation basis (with the exception of net operating assets).
(vii) Goodwill associated with Onshore US of US$3,026 million is included in Other net operating assets (2014: US$3,526 million).
(viii)Negative capital expenditure reflects movements in capital creditors.
(ix) Comprises closed mining and smelting operations in Canada and the United States.
(x) Includes statutory adjustments for the Caesar oil pipeline and the Cleopatra gas pipeline to reconcile the proportionately
consolidated business total to the statutory result.
(xi) Includes US$328 million of impairments associated with the divestment of assets in North Louisiana (Haynesville) and the
Pecos field (Permian).
Copper
Underlying EBIT for the December 2015 half year decreased by US$1.9 billion to US$101 million.
US$M
Underlying EBIT for the half year ended 31 December 2014 2,046
Net price impact(i) (1,394)
Change in volumes: productivity:
Productivity excluding Escondida grade impact (1)
Escondida grade impact (342)
Change in controllable cash costs:
Productivity excluding Escondida grade impact(ii) (26)
Escondida grade impact (299)
Change in other costs:
Exchange rates 261
Inflation (77)
Depreciation, deferred stripping and impairment 55
Other(iii) (122)
Underlying EBIT for the half year ended 31 December 2015 101
(i) Average realised price: copper US$2.12/lb (2014: US$2.98/lb).
(ii) Includes drawdown of higher-cost inventory built up in prior periods and write-downs, predominantly at Escondida, of US$578
million.
(iii)Other includes: fuel and energy; asset sales; other items (including profit from equity accounted investments).
Total copper production for the December 2015 half year decreased by six per cent to 762 kt.
• Escondida copper production decreased 18 per cent to 452 kt as record material mined,
underpinned by improvements in truck availability and utilisation, was more than offset by a 25 per
cent decline in grade.
• Pampa Norte copper production was broadly unchanged at 126 kt as record ore milled and higher
grade underpinned record production at Spence and offset lower recoveries at Cerro Colorado.
• Olympic Dam copper production increased by 37 per cent to a record 112 kt and reflects record ore
milled and improved smelter utilisation following planned maintenance in the prior period.
• Antamina copper production increased by 36 per cent to 72 kt as higher grades and recoveries
were supported by record material mined and milled.
Total copper production guidance for the 2016 financial year remains unchanged at 1.5 Mt.
• Guidance for Escondida remains unchanged at 940 kt.
• Pampa Norte production is now expected to be ahead of the prior year.
• Olympic Dam production is now expected to exceed 200 kt.
• Guidance for Antamina remains unchanged at 136 kt.
The ramp-up of the Escondida Organic Growth Project 1 (OGP1) progresses ahead of plan and is expected
to reach full capacity during the 2016 financial year. In the medium term, completion of the Escondida
Water Supply project and the potential life extension of the Los Colorados concentrator will enable
utilisation of three concentrators to offset grade decline and support a strong recovery in production(9). In
the short to medium term, the Spence Recovery Optimisation project should enable the full utilisation of
approximately 200 ktpa of tankhouse capacity.
Unit cash costs at our operated copper assets declined by eight per cent to US$1.11 per pound on an
Escondida grade-adjusted basis during the December 2015 half year. This reflects the benefit of
productivity-led cost improvements and a further reduction in labour and contractor costs, particularly at
Olympic Dam where unit costs declined by 36 per cent.
Escondida’s Underlying EBIT declined by US$1.7 billion in the December 2015 half year and reflected
lower realised prices and expected grade-related volume decline. This reduction also included inventory
movements and write-downs of US$448 million. The inventory movements reflect a build of lower-grade
inventory in prior periods in line with the optimised mine plan, followed by a partial drawdown in the
December 2015 half year. The use of lower-grade stockpiled inventory resulted in lower recoveries, which
have subsequently returned to normal levels, but provided a substantial reduction of working capital and
increased cash flow during the period.
Robust production performance and benefits from the Escondida 3.0 productivity program supported grade-
adjusted unit costs which remained broadly unchanged at US$1.02 per pound in the December 2015 half
year. Excluding the impact of inventory movements, net cash costs declined 12 per cent.
Escondida’s grade-adjusted unit cost guidance remains unchanged at US$0.87 per pound(10) for the 2016
financial year. We expect a strong recovery of concentrate production in the second half of the 2016
financial year supported by higher throughput from the continued ramp-up of OGP1 and improved
recoveries and water availability. We also expect a reduction in the average unit cost of cathode production
due to sulphide leach productivity initiatives, which include increasing the area of stacked material under
irrigation, encompassing older zones of the pad. These initiatives will result in a decline in the average cost
of sulphide leach inventory in the second half of the 2016 financial year. In addition, the use of lower-grade
ore stocks will support a 45 per cent increase in material stacked over the period to maintain optimal
cathode production in the 2017 and 2018 financial years.
Escondida unit costs (US$M) H1 FY16 H2 FY15 H1 FY15 FY15
Revenue 2,197 4,099 3,720 7,819
Underlying EBITDA 428 1,937 2,127 4,064
Cash costs (gross) 1,769 2,162 1,593 3,755
Less: one-off items - 188 - 188
Less: by-product credits 74 98 79 177
Less: freight 37 56 61 117
Less: treatment and refining charges 153 263 211 474
Cash costs (net)(i) 1,505 1,557 1,242 2,799
Sales (kt, equity share)(ii) 470 696 563 1,259
Sales (Mlb, equity share)(ii) 1,037 1,534 1,241 2,775
Cash cost per pound (US$) 1.45 1.01 1.00 1.01
Escondida grade adjustment(iii) 0.43 Base year Base year Base year
Adjusted cash cost per pound (US$) 1.02 1.01 1.00 1.01
(i) Royalties are reported within taxation expense. Comparative periods have been restated to exclude by-product credits.
(ii) Sales volumes adjusted to exclude intercompany sales and purchases.
(iii)Adjustment to present unit cost on a grade-equivalent basis relative to the 2015 financial year.
Lower depreciation and deferred stripping largely reflects a reduction at Escondida and Cerro Colorado in
line with lower production.
Financial information for the Copper business for the December 2015 and December 2014 half years is
presented below.
Half year ended Net
31 December 2015 Underlying Underlying operating Capital Exploration Exploration to
US$M Revenue EBITDA D&A EBIT assets expenditure gross profit
Escondida(i) 2,197 428 416 12 14,106 1,334
Pampa Norte(ii) 506 211 189 22 1,879 155
Antamina(iii) 453 203 56 147 1,352 106
Olympic Dam 770 190 118 72 6,424 107
Other(iii)(iv) - (72) 6 (78) (125) -
Total Copper from 3,926 960 785 175 23,636 1,702
Group production
Third party products 420 (22) - (22) - -
Total Copper 4,346 938 785 153 23,636 1,702 34 34
Adjustment for equity (453) (109) (57) (52) - (106) (1) (1)
accounted investments
Total Copper
statutory result 3,893 829 728 101 23,636 1,596 33 33
Half year ended
31 December 2014 Net
(Restated) Underlying Underlying operating Capital Exploration Exploration to
US$M Revenue EBITDA D&A EBIT assets expenditure gross profit
Escondida(i) 3,720 2,127 418 1,709 12,862 1,671
Pampa Norte(ii) 794 447 222 225 2,400 95
Antamina(iii) 467 250 52 198 1,391 101
Olympic Dam 797 138 132 6 6,408 131
Other(iii)(iv) - (58) 4 (62) (26) -
Total Copper from
Group production 5,778 2,904 828 2,076 23,035 1,998
Third party products 470 11 - 11 - -
Total Copper 6,248 2,915 828 2,087 23,035 1,998 42 42
Adjustment for equity
accounted investments (467) (94) (53) (41) - (101) (1) (1)
Total Copper
statutory result 5,781 2,821 775 2,046 23,035 1,897 41 41
(i) Escondida is consolidated under IFRS 10 and reported on a 100 per cent basis.
(ii) Includes Spence and Cerro Colorado.
(iii)Antamina and Resolution are equity accounted investments and are reported on a proportionate consolidation basis (with the
exception of net operating assets).
(iv) Predominantly comprises divisional activities, greenfield exploration, business development and ceased and sold operations.
Includes Resolution.
Iron Ore
Underlying EBIT for the December 2015 half year decreased by US$2.3 billion to US$1.9 billion.
US$M
Underlying EBIT for the half year ended 31 December 2014 4,200
Net price impact(i) (2,828)
Change in volumes: productivity 175
Change in controllable cash costs 146
Change in other costs:
Exchange rates 278
Inflation (32)
Other(ii) (12)
Underlying EBIT for the half year ended 31 December 2015 1,927
(i) Average realised price: iron ore US$43/wmt, FOB (2014: US$70/wmt, FOB).
(ii) Other includes: fuel and energy; depreciation, deferred stripping and impairment; asset sales; other items. Other items includes
net profit from the equity accounted investment in Samarco, but does not include any financial impacts following the Samarco
dam failure which has been treated as an exceptional item.
Total iron ore production for the December 2015 half year increased by four per cent to 118 Mt.
• Western Australia Iron Ore (WAIO) production increased by six per cent to a record 131 Mt (100 per
cent basis), underpinned by the Jimblebar mining hub operating at full capacity and improved ore
handling plant utilisation at Newman.
• Samarco production decreased by 25 per cent to 11 Mt (100 per cent basis). Mining and processing
operations remain suspended following the dam failure. The final shipment of pellets from port
stockpiles is expected to be completed in the March 2016 quarter.
Total iron ore production for the 2016 financial year of 237 Mt is expected, four per cent lower than prior
guidance.
• Revision of total iron ore guidance reflects the suspension of operations at Samarco.
• WAIO guidance remains unchanged at 270 Mt (100 per cent basis). However, following
unfavourable weather conditions in January we will continue to monitor progress against guidance
and will provide an update in the March 2016 operational review if required.
Work has commenced on the installation of a new primary crusher and additional conveying capacity at
Jimblebar. Associated costs are included within WAIO’s average annual sustaining capital expenditure
which is now expected to be approximately US$4 per tonne following continued improvements in capital
productivity. The ramp-up of additional capacity at the Jimblebar mining hub along with further productivity
improvements, will deliver an increase in system capacity to 290 Mtpa over time.
WAIO unit cash costs declined by 25 per cent to US$15.21 per tonne, underpinned by a stronger US dollar,
reductions in labour and contractor costs, and lower diesel prices and consumption. Unit cost guidance for
the 2016 financial year remains unchanged at US$15 per tonne(10).
WAIO unit costs (US$M) H1 FY16 H2 FY15 H1 FY15 FY15
Revenue 5,247 6,245 8,193 14,438
Underlying EBITDA 2,703 3,519 4,778 8,297
Cash costs (gross) 2,544 2,726 3,415 6,141
Less: freight 469 397 658 1,055
Less: royalties 366 425 554 979
Cash costs (net) 1,709 1,904 2,203 4,107
Sales (kt, equity share) 112,393 111,916 108,245 220,161
Cash cost per tonne (US$) 15.21 17.01 20.35 18.65
The sale of BHP Billiton’s 100 per cent interest in its Liberia iron ore project to Cavalla Resources was
completed in October 2015.
Financial information for the Iron Ore business for the December 2015 and December 2014 half years is
presented below.
Half year ended Net
31 December 2015 Underlying Underlying operating Capital Exploration Exploration to
US$M Revenue EBITDA D&A EBIT assets expenditure gross profit
Western Australia Iron Ore 5,247 2,703 894 1,809 22,137 497
Samarco(i) 442 196 46 150 9 34
Other(ii) 60 (5) 2 (7) 118 56
Total Iron Ore from 5,749 2,894 942 1,952 22,264 587
Group production
Third party products(iii) 42 (9) - (9) - -
Total Iron Ore 5,791 2,885 942 1,943 22,264 587 46 30
Adjustment for equity (442) (62) (46) (16) - (34)
accounted investments - -
Total Iron Ore
statutory result 5,349 2,823 896 1,927 22,264 553 46 30
Half year ended Net
31 December 2014 Underlying Underlying operating Capital Exploration Exploration to
US$M Revenue EBITDA D&A EBIT assets expenditure gross profit
Western Australia Iron Ore 8,193 4,778 791 3,987 23,289 1,090
Samarco(i) 828 420 54 366 1,036 165
Other(ii) 73 4 1 3 108 14
Total Iron Ore from
Group production 9,094 5,202 846 4,356 24,433 1,269
Third party products(iii) 152 (5) - (5) - -
Total Iron Ore 9,246 5,197 846 4,351 24,433 1,269 71 16
Adjustment for equity
accounted investments (828) (205) (54) (151) - (165) - -
Total Iron Ore
statutory result 8,418 4,992 792 4,200 24,433 1,104 71 16
(i) Samarco is an equity accounted investment and is reported on a proportionate consolidation basis (with the exception of net
operating assets).
(ii) Predominantly comprises divisional activities, towage services, business development and ceased operations.
(iii)Includes inter-segment and external sales of contracted gas purchases.
Coal
Underlying EBIT for the December 2015 half year decreased by US$481 million to US$(342) million.
US$M
Underlying EBIT for the half year ended 31 December 2014 139
Net price impact(i) (608)
Change in volumes: productivity 2
Change in controllable cash costs 41
Change in other costs:
Exchange rates 337
Inflation (26)
Depreciation, deferred stripping and impairment (89)
One-off items(ii) (118)
Other(iii) (20)
Underlying EBIT for the half year ended 31 December 2015 (342)
(i) Average realised price: hard coking coal US$82/t (2014: US$110/t); weak coking coal US$67/t (2014: US$92/t); thermal coal
US$49/t (2014: US$61/t).
(ii) One-off items reflect royalty and taxation matters.
(iii)Other includes: fuel and energy; asset sales; ceased and sold operations; other items (including loss from equity accounted
investments).
Metallurgical and energy coal production both declined by three per cent, to 21 Mt and 19 Mt respectively,
in the December 2015 half year.
• Record metallurgical coal production at four Queensland Coal mines was offset by a convergence
event at the Broadmeadow mine and completion of longwall mining at the low-cost Crinum mine.
• First metallurgical coal production from the Haju mine in Indonesia was achieved.
• Drought conditions at Cerrejón and heavy rainfall and blasting constraints at New South Wales
Energy Coal reduced energy coal production.
Metallurgical coal production guidance for the 2016 financial year remains unchanged at 40 Mt. Energy
coal production for the 2016 financial year is now expected to be 37 Mt following completion of the sale of
the San Juan Mine to Westmoreland Coal Company on 31 January 2016.
Queensland Coal unit cash costs declined by 17 per cent to US$59 per tonne, as the operations benefited
from a stronger US dollar, lower diesel prices and a reduction in labour and contractor costs reflecting
continued productivity improvements. This offset inventory write-downs due to weaker coal prices, the
impact of a convergence event at the Broadmeadow mine, a higher than usual number of planned
maintenance shutdowns, and costs associated with the closure of the Crinum mine as it reached the end of
its economic reserve life. Unit costs for the 2016 financial year are now expected to be US$59 per
tonne(10), as favourable currency movements offset the removal of low-cost Crinum volumes.
Queensland Coal unit costs (US$M) H1 FY16 H2 FY15 H1 FY15 FY15
Revenue 1,623 1,970 2,251 4,221
Underlying EBITDA 122 528 478 1,006
Cash costs (gross) 1,501 1,442 1,773 3,215
Less: freight 52 63 111 174
Less: royalties 218 144 146 290
Cash costs (net) 1,231 1,235 1,516 2,751
Sales (kt, equity share) 20,974 20,861 21,428 42,289
Cash cost per tonne (US$) 58.69 59.20 70.75 65.05
Higher depreciation in the December 2015 half year reflects the completion of the Hay Point Stage Three
Expansion and accelerated depreciation related to the closure of the Crinum mine. Queensland Coal’s
average annual sustaining capital expenditure is expected to be approximately US$6 per tonne.
Financial information for the Coal business for the December 2015 and December 2014 half years is
presented below.
Half year ended Net
31 December 2015 Underlying Underlying operating Capital Exploration Exploration to
US$M Revenue EBITDA D&A EBIT assets expenditure gross profit
Queensland Coal 1,623 122 410 (288) 8,788 155
New Mexico 251 75 22 53 160 3
New South Wales Energy Coal(i) 511 68 77 (9) 1,229 11
Colombia(i) 283 80 49 31 840 17
Other(ii) - (53) 4 (57) 208 19
Total Coal from 2,668 292 562 (270) 11,225 205
Group production
Third party products - - - - - -
Total Coal 2,668 292 562 (270) 11,225 205 9 9
Adjustment for equity (331) (137) (65) (72) - (20)
accounted investments(iii) - -
Total Coal
statutory result 2,337 155 497 (342) 11,225 185 9 9
Half year ended
31 December 2014 Net
(Restated) Underlying Underlying operating Capital Exploration Exploration to
US$M Revenue EBITDA D&A EBIT assets expenditure gross profit
Queensland Coal 2,251 478 331 147 9,450 369
New Mexico 298 86 23 63 250 13
New South Wales Energy Coal(i) 640 136 78 58 1,419 108
Colombia(i) 383 121 56 65 938 54
Other(ii) - (64) 1 (65) 183 8
Total Coal from 3,572 757 489 268 12,240 552
Group production
Third party products 7 - - - 1 -
Total Coal 3,579 757 489 268 12,241 552 12 12
Adjustment for equity (436) (199) (70) (129) - (74)
accounted investments(iii) - -
Total Coal
statutory result 3,143 558 419 139 12,241 478 12 12
(i) Newcastle Coal Infrastructure Group and Cerrejón are equity accounted investments and are reported on a proportionate
consolidation basis (with the exception of net operating assets).
(ii) Predominantly comprises divisional activities and greenfield projects.
(iii)Includes statutory adjustments for Newcastle Coal Infrastructure Group and Cerrejón to reconcile the proportionately
consolidated business total to the statutory result. Statutory Underlying EBIT includes net finance costs and taxation expense
of US$51 million (2014: US$78 million).
Group and unallocated items
Underlying EBIT expense decreased by US$157 million to US$145 million in the December 2015 half year.
The reduction reflected transaction costs associated with the successful demerger of South32 incurred in
the prior period, the favourable exchange rate impact on Nickel West costs, and lower corporate
overheads. This more than offset lower average realised prices received by Nickel West.
Resources and reserves assessment
Samarco is reviewing the operation’s resources and reserves following the dam failure. BHP Billiton is
continuing to work closely with Samarco and we expect to provide updated information as soon as we are
in a position to do so.
The financial information on pages 29 to 50 has been prepared in accordance with IFRS. This news release including
the financial information is unaudited. Variance analysis relates to the relative financial and/or production performance
of BHP Billiton and/or its operations during the December 2015 half year compared with the December 2014 half year,
unless otherwise noted.
The following abbreviations may have been used throughout this report: barrels (bbl); billion cubic feet (bcf); barrels of
oil equivalent (boe); 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 equivalent per day (MMboe/d); thousand cubic feet equivalent (Mcfe); million
cubic feet per day (MMcf/d); million pounds (Mlb); 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).
The following footnotes apply to this profit release:
(1) Underlying attributable profit, Underlying EBIT and Underlying EBITDA are used to reflect the underlying
performance of BHP Billiton. We believe that these non-IFRS measures provide useful information, but should
not be considered as an indication of, or as an alternative to, Attributable (loss)/profit as an indicator of actual
operating performance or as an alternative to cash flow as a measure of liquidity.
• Underlying attributable profit is Attributable (loss)/profit excluding discontinued operations and any exceptional
items and minority interest in exceptional items.
• Underlying EBIT is earnings before net finance costs, taxation, discontinued operations and any exceptional
items. Underlying EBIT is reported net of net finance costs and taxation expense of US$119 million (2014:
US$270 million) related to equity accounted investments and excludes exceptional items of US$655 million
2014: US$ nil) related to equity accounted investments.
• Underlying EBITDA is Underlying EBIT before depreciation, impairments and amortisation of US$4,652 million
for the half year ended 31 December 2015 and US$4,762 million for the half year ended 31 December 2014.
Underlying EBITDA is reported net of net finance costs and taxation benefit/(expense), depreciation,
impairments and amortisation related to equity accounted investments of US$274 million (2014: US$435
million) and excludes exceptional items of US$655 million (2014: US$ nil) related to equity accounted
investments.
(2) Further non-IFRS measures are defined as follows and comparatives exclude discontinued operations unless
otherwise stated:
• Adjusted effective tax rate – comprises Total taxation benefit/(expense) excluding remeasurement of deferred
tax assets associated with the Minerals Resource Rent Tax (MRRT), exceptional items and exchange rate
movements included in taxation benefit/(expense) divided by (Loss)/profit before taxation and exceptional
items.
• Free cash flow – comprises net operating cash flows less net investing cash flows.
• Gearing ratio – represents the ratio of net debt to net debt plus net assets.
• Net debt – comprises Interest bearing liabilities less Cash and Cash equivalents for the total operations within
the Group at the reporting date.
• Net operating assets – represents operating assets net of operating liabilities including the carrying value of
equity accounted investments and predominantly excludes cash balances, interest bearing liabilities and
deferred tax balances. The carrying value of investments accounted for using the equity accounted method
represents the balance of the Group’s investment in equity accounted investments, with no adjustment for any
cash balances, interest bearing liabilities and deferred tax balances of the equity accounted investment.
• Underlying basic (loss)/earnings per share – represents basic (loss)/earnings per share excluding any
exceptional items.
• Underlying EBIT margin – comprises Underlying EBIT excluding third party product (loss)/profit from
operations, divided by revenue excluding third party product revenue.
• Underlying EBITDA margin – comprises Underlying EBITDA excluding third party product EBITDA, divided by
revenue excluding third party product revenue.
(3) Escondida unit cost is presented on a grade-adjusted basis relative to the 2015 financial year to reflect a large
decline in grades. Comparative periods have been restated to exclude by-product credits.
(4) Represents the share of capital and exploration expenditure attributable to BHP Billiton shareholders on a cash
basis. Includes BHP Billiton proportionate share of equity accounted investments; excludes capitalised deferred
stripping and non-controlling interests.
(5) The 31 December 2014 information in this report has been presented on a continuing operations basis to exclude
the contribution from assets that were demerged with South32, unless otherwise noted. The prior period’s
contribution of the South32 assets to the Group’s results are disclosed as discontinued operations within the
Group’s financial statements.
(6) Represents productivity-led volume efficiencies, operating cash cost efficiencies and exploration and business
development savings on a continuing operations basis. Productivity-led volume efficiencies refer to volume
increases, excluding volume increases from major capital projects, multiplied by the prior period Underlying EBIT
margin. Operating cash cost efficiencies refer to the reduction in costs, excluding the impact of volume, price-
linked costs, exchange rates, inflation, fuel and energy, non-cash costs, one-off items, ceased and sold
operations and other items. Exploration and business development savings refers to the reduction in total
exploration and business development costs including capitalised exploration.
(7) Movement in underlying net cash costs excludes inventory movements and write-downs of US$448 million.
(8) Depreciation, deferred stripping and impairment also includes amortisation.
(9) Subject to Escondida Owners Council approval.
(10)WAIO and Queensland Coal unit cash costs exclude freight and royalties; Escondida unit cash costs exclude
freight and treatment and refining charges. Escondida grade-adjusted unit cost is on a 2015 financial year grade-
equivalent basis. 2016 financial year guidance is based on exchange rates of AUD/USD 0.72 and USD/CLP 702.
Forward looking statements
This release 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 release. Readers are cautioned not
to put undue reliance on forward-looking statements.
For example, our future revenues from our operations, projects or mines described in this release 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 U.S. 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 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 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.
No offer of securities
Nothing in this release 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 release 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 release should not be relied upon as a recommendation or forecast by BHP Billiton.
No financial or investment advice – South Africa
BHP Billiton does not provide any financial or investment 'advice' as that term is defined in the South African Financial
Advisory and Intermediary Services Act, 37 of 2002, and we strongly recommend that you seek professional advice.
Sponsor: Merrill Lynch South Africa Proprietary Limited
Further information on BHP Billiton can be found at: bhpbilliton.com
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BHP Billiton Group
Financial Report
Half year ended 31 December 2015
Contents
Half Year Financial Statements Page
Consolidated Income Statement for the half year ended 31 December 2015 31
Consolidated Statement of Comprehensive Income for the half year ended 31 December
2015 32
Consolidated Balance Sheet as at 31 December 2015 33
Consolidated Cash Flow Statement for the half year ended 31 December 2015 34
Consolidated Statement of Changes in Equity for the half year ended 31 December 2015 35
Notes to the Financial Information 36
1. Accounting policies 36
2. Segment reporting 37
3. Exceptional items 39
4. Interests in associates and joint venture entities 40
5. Net finance costs 40
6. Earnings per share 41
7. Dividends 42
8. Financial risk management – Fair values 43
9. Significant events – Samarco dam failure 47
10.Subsequent events 50
Directors’ Report 51
Directors’ Declaration of Responsibility 53
Lead Auditor’s Independence Declaration under Section 307C of the Corporations Act 2001 54
Independent Review Report 55
Comparative information for the half year ended 31 December 2014 has been restated for the effects of the
application of IFRS 5/AASB 5 ‘Non-current Assets Held for Sale and Discontinued Operations’ following the
demerger of South32. The Consolidated Statement of Comprehensive Income, the Consolidated Balance
Sheet and the Consolidated Statement of Changes in Equity for this period are not required to be restated.
Consolidated Income Statement
for the half year ended 31 December 2015
Notes Half year ended Half year ended Year ended
31 Dec 31 Dec 30 June
2015 2014 2015
US$M US$M US$M
Restated
Continuing operations
Revenue
Group production 15,157 24,230 43,457
Third party products 555 630 1,179
Revenue 2 15,712 24,860 44,636
Other income 251 284 496
Expenses excluding net finance costs (21,998) (17,549) (37,010)
(Loss)/profit from equity accounted investments (995)
and related impairments 4 335 548
(Loss)/profit from operations (7,030) 7,930 8,670
Comprising:
Group production (7,003) 7,929 8,656
Third party products (27) 1 14
(7,030) 7,930 8,670
Financial expenses (492) (275) (702)
Financial income 63 41 88
Net finance costs 5 (429) (234) (614)
(Loss)/profit before taxation (7,459) 7,696 8,056
Income tax benefit/(expense) 1,816 (2,456) (2,762)
Royalty related taxation (net of income tax
benefit) (90) (848) (904)
Total taxation benefit/(expense) 1,726 (3,304) (3,666)
(Loss)/profit after taxation from continuing
operations (5,733) 4,392 4,390
Discontinued operations
Profit/(loss) after taxation from discontinued
operations - 401 (1,512)
(Loss)/profit after taxation (5,733) 4,793 2,878
Attributable to non-controlling interests (64) 528 968
Attributable to members of BHP Billiton Group (5,669) 4,265 1,910
Basic (loss)/earnings per ordinary share (cents) 6 (106.5) 80.2 35.9
Diluted (loss)/earnings per ordinary share (cents) 6 (106.2) 80.0 35.8
Basic (loss)/earnings from continuing operations
per ordinary share (cents) 6 (106.5) 73.6 65.5
Diluted (loss)/earnings from continuing operations
per ordinary share (cents) 6 (106.2) 73.4 65.3
Dividends per ordinary share – paid during the
period (cents) 7 62.0 62.0 124.0
Dividends per ordinary share – determined in
respect of the period (cents) 7 16.0 62.0 124.0
The accompanying notes form part of this financial information.
Consolidated Statement of Comprehensive Income
for the half year ended 31 December 2015
Half year Half year Year ended
ended ended 30 June
31 Dec 2015 31 Dec 2014 2015
US$M US$M US$M
(Loss)/profit after taxation (5,733) 4,793 2,878
Other comprehensive income
Items that may be reclassified subsequently to the income
statement:
Available for sale investments:
Net valuation losses taken to equity (3) (19) (21)
Net valuation gains transferred to the income statement - (1) (115)
Cash flow hedges:
Losses taken to equity (666) (1,296) (1,797)
Losses transferred to the income statement 646 1,283 1,815
Exchange fluctuations on translation of foreign operations taken - (2) (2)
to equity
Tax recognised within other comprehensive income 7 6 29
Total items that may be reclassified subsequently to the income (16) (29) (91)
statement
Items that will not be reclassified to the income statement:
Remeasurement gains/(losses) on pension and medical schemes 5 (29) (28)
Tax recognised within other comprehensive income (11) 13 (17)
Total items that will not be reclassified to the income statement (6) (16) (45)
Total other comprehensive loss (22) (45) (136)
Total comprehensive (loss)/income (5,755) 4,748 2,742
Attributable to non-controlling interests (64) 533 973
Attributable to members of BHP Billiton Group (5,691) 4,215 1,769
The accompanying notes form part of this financial information.
Consolidated Balance Sheet
as at 31 December 2015
31 Dec 2015 30 June 2015
US$M US$M
ASSETS
Current assets
Cash and cash equivalents 10,626 6,753
Trade and other receivables 2,903 4,321
Other financial assets 75 83
Inventories 3,914 4,292
Current tax assets 676 658
Other 189 262
Total current assets 18,383 16,369
Non-current assets
Trade and other receivables 1,296 1,499
Other financial assets 1,181 1,159
Inventories 378 466
Property, plant and equipment 85,439 94,072
Intangible assets 4,214 4,292
Investments accounted for using the equity method 2,577 3,712
Deferred tax assets 5,082 2,861
Other 119 150
Total non-current assets 100,286 108,211
Total assets 118,669 124,580
LIABILITIES
Current liabilities
Trade and other payables 5,678 7,389
Interest bearing liabilities 4,071 3,201
Other financial liabilities 243 251
Current tax payable 171 207
Provisions 1,368 1,676
Deferred income 107 129
Total current liabilities 11,638 12,853
Non-current liabilities
Trade and other payables 22 29
Interest bearing liabilities 32,476 27,969
Other financial liabilities 1,622 1,031
Deferred tax liabilities 4,002 4,542
Provisions 7,183 7,306
Deferred income 296 305
Total non-current liabilities 45,601 41,182
Total liabilities 57,239 54,035
Net assets 61,430 70,545
EQUITY
Share capital – BHP Billiton Limited 1,186 1,186
Share capital – BHP Billiton Plc 1,057 1,057
Treasury shares (42) (76)
Reserves 2,474 2,557
Retained earnings 51,111 60,044
Total equity attributable to members of BHP Billiton Group 55,786 64,768
Non-controlling interests 5,644 5,777
Total equity 61,430 70,545
The accompanying notes form part of this financial information.
Consolidated Cash Flow Statement
for the half year ended 31 December 2015
US$M Half year Half year Year ended
ended ended 30 June
31 Dec 2015 31 Dec 2014 2015
Restated
Operating activities
(Loss)/profit before taxation (7,459) 7,696 8,056
Adjustments for:
Non-cash or non-operating exceptional items 8,369 409 3,196
Depreciation and amortisation expense 4,602 4,401 9,158
Impairments of property, plant and equipment, financial assets and
intangibles 50 361 828
Net gain on sale of non-current assets (3) (33) (9)
Employee share awards expense 77 116 247
Net finance costs 429 234 614
Share of operating profit of equity accounted investments (185) (335) (548)
Other 176 85 265
Changes in assets and liabilities:
Trade and other receivables 1,611 1,008 1,431
Inventories 446 (189) 151
Trade and other payables (1,262) (1,210) (990)
Net other financial assets and liabilities (83) (8) (8)
Provisions and other liabilities (474) (589) (771)
Cash generated from operations 6,294 11,946 21,620
Dividends received 1 4 17
Dividends received from equity accounted investments 170 476 723
Interest received 60 45 86
Interest paid (342) (310) (627)
Income tax refunded 452 329 348
Income tax paid (1,127) (2,013) (3,225)
Royalty-related taxation paid (248) (861) (1,148)
Net operating cash flows from continuing operations 5,260 9,616 17,794
Net operating cash flows from discontinued operations - 807 1,502
Net operating cash flows 5,260 10,423 19,296
Investing activities
Purchases of property, plant and equipment (3,958) (6,361) (11,947)
Exploration expenditure (410) (409) (816)
Exploration expenditure expensed and included in operating cash flows 199 350 670
Purchase of intangibles (2) (64) (98)
Investment in financial assets (54) (18) (15)
Investment in equity accounted investments (29) (25) (71)
Cash outflows from investing activities (4,254) (6,527) (12,277)
Proceeds from sale of property, plant and equipment 71 41 66
Proceeds from sale of intangibles 5 - 8
Proceeds from financial assets 92 333 445
Proceeds from divestment of subsidiaries, operations and joint 48 251 256
operations, net of their cash
Net investing cash flows from continuing operations (4,038) (5,902) (11,502)
Net investing cash flows from discontinued operations - (415) (1,066)
Cash disposed on demerger of South32 - - (586)
Net investing cash flows (4,038) (6,317) (13,154)
Financing activities
Proceeds from interest bearing liabilities 7,019 341 3,440
Proceeds/(settlements) from debt related instruments 129 - (33)
Repayment of interest bearing liabilities (1,006) (2,953) (4,135)
Proceeds from ordinary shares - 3 9
Contributions from non-controlling interests 2 46 53
Purchase of shares by Employee Share Ownership Plan (ESOP)
Trusts (69) (338) (355)
Dividends paid (3,266) (3,209) (6,498)
Dividends paid to non-controlling interests (71) (327) (554)
Net financing cash flows from continuing operations 2,738 (6,437) (8,073)
Net financing cash flows from discontinued operations - (322) (203)
Net financing cash flows 2,738 (6,759) (8,276)
Net increase/(decrease) in cash and cash equivalents from
continuing operations 3,960 (2,723) (1,781)
Net increase in cash and cash equivalents from discontinued
operations - 70 233
Cash and cash equivalents, net of overdrafts, at beginning of period 6,613 8,752 8,752
Cash disposed on demerger of South32 - - (586)
Foreign currency exchange rate changes on cash and cash
equivalents 9 19 (5)
Cash and cash equivalents, net of overdrafts, at end of period 10,582 6,118 6,613
The accompanying notes form part of this financial information.
Consolidated Statement of Changes in Equity
for the half year ended 31 December 2015
For the half year ended 31
December 2015
US$M Attributable to members of BHP Billiton Group
Share capital
Total equity
attributable
to members
BHP BHP of BHP Non-
Billiton Billiton Treasury Retained Billiton controlling Total
Limited Plc shares Reserves earnings Group interests equity
Balance as at 1 July 2015 1,186 1,057 (76) 2,557 60,044 64,768 5,777 70,545
Total comprehensive loss - - - (16) (5,675) (5,691) (64) (5,755)
Transactions with owners:
Purchase of shares by ESOP Trusts - - (69) - - (69) - (69)
Employee share awards exercised net
of employee contributions and other
adjustments - - 103 (124) 21 - - -
Employee share awards forfeited - - - (20) 20 - - -
Accrued employee entitlement for
unexercised awards - - - 77 - 77 - 77
Dividends - - - - (3,299) (3,299) (71) (3,370)
Equity contributed - - - - - - 2 2
Balance as at 31 December 2015 1,186 1,057 (42) 2,474 51,111 55,786 5,644 61,430
Balance as at 1 July 2014 1,186 1,069 (587) 2,927 74,548 79,143 6,239 85,382
Total comprehensive income - - - (34) 4,249 4,215 533 4,748
Transactions with owners:
Shares cancelled - (12) 501 12 (501) – - –
Purchase of shares by ESOP Trusts - - (338) - - (338) - (338)
Employee share awards exercised net
of employee contributions - - 194 (174) (18) 2 - 2
Employee share awards forfeited - - - (4) 4 - - –
Accrued employee entitlement for
unexercised awards - - - 116 - 116 - 116
Distribution to option holders - - - (1) - (1) (1) (2)
Dividends - - - - (3,292) (3,292) (412) (3,704)
Equity contributed - - - - - – 46 46
Balance as at 31 December 2014 1,186 1,057 (230) 2,842 74,990 79,845 6,405 86,250
The accompanying notes form part of this financial information.
Notes to the Financial Information
1. Accounting policies
This general purpose financial report for the half year ended 31 December 2015 is unaudited and has been
prepared in accordance with IAS 34 “Interim Financial Reporting” as issued by the International Accounting
Standards Board (IASB), IAS 34 “Interim Financial Reporting” as adopted by the EU, AASB 134 “Interim
Financial Reporting” as issued by the Australian Accounting Standards Board (AASB) and the Disclosure
and Transparency Rules of the Financial Conduct Authority in the United Kingdom and the Australian
Corporations Act 2001 as applicable to interim financial reporting.
The half year financial statements represent a “condensed set of financial statements” as referred to in the
UK Disclosure and Transparency Rules issued by the Financial Conduct Authority. Accordingly, they do not
include all of the information required for a full annual report and are to be read in conjunction with the most
recent annual financial report. The comparative figures for the financial year ended 30 June 2015 are not
the statutory accounts of the BHP Billiton Group for that financial year. Those accounts, which were
prepared under IFRS, have been reported on by the Company's auditor and delivered to the registrar of
companies. The auditor has reported on those accounts; the report was unqualified, did not include a
reference to any matters to which the auditors drew attention by way of emphasis without qualifying their
report and did not contain statements under Section 498 (2) or (3) of the UK Companies Act 2006.
The half year financial statements have been prepared on the basis of the accounting policies and methods
of computation consistent with those applied in the 30 June 2015 annual financial statements contained
within the Annual Report of the BHP Billiton Group.
Rounding of amounts
Amounts in this financial report have, unless otherwise indicated, been rounded to the nearest million
dollars.
Comparatives
Where applicable, comparative periods have been adjusted to disclose them on the same basis as the
current period figures. The 31 December 2014 financial information has been restated for the effects of the
application of IFRS 5/AASB 5 ‘Non-current Assets Held for Sale and Discontinued Operations’ following the
demerger of South32 in May 2015. The nature of each change reflected in the restated financial information
is as follows:
• All income and expense items relating to South32 have been removed from the individual line items
in the Consolidated Income Statement. The post-tax (loss)/profit of South32 is presented as a single
amount in the line item entitled “(Loss)/Profit after taxation from discontinued operations”; and
• All cash flows and other items relating to South32 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 South32 and the cash disposed of on demerger of South32 are each
disclosed in single amount 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.
2. Segment reporting
The Group operates four businesses aligned with the commodities which we extract and market, reflecting
the structure used by the Group’s management to assess the performance of the Group.
Reportable segment Principal activities
Petroleum Exploration, development and production of oil and gas
Copper Mining of copper, silver, lead, zinc, molybdenum, uranium and gold
Iron Ore Mining of iron ore
Coal Mining of metallurgical coal and thermal (energy) coal
Group and unallocated items comprises Group Functions, other unallocated operations including Potash
(previously disclosed in the former Petroleum and Potash reporting segment) and Nickel West,
consolidation adjustments and external sales of freight and fuel to third parties. Comparative periods have
been restated to reflect the segment reporting change relating to Potash.
Exploration and technology activities are recognised within relevant segments.
It is the Group’s policy that inter-segment sales are made on a commercial basis.
The comparative periods segment reporting information excludes discontinued operations following the
demerger of South32, being BHP Billiton’s former interests in its integrated Aluminium business,
Manganese business and the Cerro Matoso nickel operation, Energy Coal South Africa, Illawarra
metallurgical coal and the Cannington silver-lead-zinc mine. The half year ended 31 December
comparative period has been restated.
2. Segment reporting (continued)
US$M Petroleum Copper Iron Ore Coal Group and BHP
unallocated Billiton
items/ Group
eliminations
Half year ended 31 December 2015
Revenue
Group production 3,546 3,473 5,247 2,337 388 14,991
Third party products 88 420 31 - 16 555
Rendering of services 106 - 60 - - 166
Inter-segment revenue 60 - 11 - (71) -
Total revenue(a) 3,800 3,893 5,349 2,337 333 15,712
Underlying EBIT(b) (199) 101 1,927 (342) (145) 1,342
Exceptional items(c) (7,184) - (1,180) - (8) (8,372)
Net finance costs(d) (429)
(Loss)/profit before taxation (7,459)
Half year ended 31 December 2014
Restated
Revenue
Group production 6,659 5,311 8,193 3,136 776 24,075
Third party products 44 470 65 7 44 630
Rendering of services 82 - 73 - - 155
Inter-segment revenue 151 - 87 - 238) -
Total revenue(a) 6,936 5,781 8,418 3,143 582 24,860
Underlying EBIT(b) 2,256 2,046 4,200 139 (302) 8,339
Exceptional items(c) - - - - (409) (409)
Net finance costs(d) (234)
Profit before taxation 7,696
Year ended 30 June 2015
Revenue
Group production 10,912 10,500 14,438 5,878 1,395 43,123
Third party products 69 953 76 7 74 1,179
Rendering of services 199 - 135 - - 334
Inter-segment revenue 267 - 104 - (371) -
Total revenue(a) 11,447 11,453 14,753 5,885 1,098 44,636
Underlying EBIT(b) 1,986 3,353 6,932 348 (753) 11,866
Exceptional items(c) (2,787) - - - (409) (3,196)
Net finance costs(d) (614)
Profit before taxation 8,056
(a) Revenue not attributable to reportable segments comprises the sale of freight and fuel to third parties.
(b) Underlying EBIT is earnings before net finance costs, taxation benefit/(expense), discontinued operations and any exceptional
items. Underlying EBIT is reported net of the Group’s share of net finance costs and taxation benefit/(expense) related to equity
accounted investments and excludes exceptional items related to equity accounted investments.
(c) Refer to note 3 Exceptional items.
(d) Refer to note 5 Net finance costs.
3. Exceptional items
Exceptional items are those items where their nature and amount is considered material to the financial
statements. Such items included within the Group’s loss for the half year are detailed below.
Half year ended 31 December 2015 Gross Tax Net
US$M US$M US$M
Exceptional items by category
Samarco dam failure (1,188) 330 (858)
Impairment of Onshore US assets(a) (7,184) 2,300 (4,884)
Global taxation matters – (390) (390)
Total (8,372) 2,240 (6,132)
(a) Includes amounts attributable to non-controlling interests of US$(51) million after tax benefit.
Samarco Mineração S.A (Samarco) dam failure
The exceptional loss of US$1,188 million related to the dam failure at Samarco in November 2015
comprises the following:
Half year ended 31 December 2015 US$M
Share of loss relating to the Samarco dam failure (655)
Impairment of the carrying value of the investment in Samarco (525)
Costs incurred directly by BHP Billiton in relation to the Samarco dam failure (8)
Total(a) (1,188)
(a) Refer to note 9 Significant events for information regarding the financial impact of the Samarco dam failure in November 2015
on BHP Billiton’s share of Samarco’s operating profit.
Impairment of Onshore US assets
On 15 January 2016, the Group announced it would recognise an impairment charge of US$4.9 billion
(after tax benefit) against the carrying value of its Onshore US assets in the half year ended 31 December
2015. The impairment reflects changes to price assumptions, discount rates and development plans. This
follows significant volatility and much weaker prices experienced in the oil and gas industry which have
more than offset our substantial productivity improvements.
Global taxation matters
Global taxation matters include amounts provided for in relation to unresolved taxation disputes.
Half year ended 31 December 2014 Gross Tax Net
Restated US$M US$M US$M
Exceptional items by category
Impairment of Nickel West assets (409) 119 (290)
Repeal of Minerals Resource Rent Tax legislation(a) - (698) (698)
Total (409) (579) (988)
(a) Includes amounts attributable to non-controlling interests of US$(12) million.
Year ended 30 June 2015 Gross Tax Net
US$M US$M US$M
Exceptional items by category
Impairment of Onshore US assets (2,787) 829 (1,958)
Impairment of Nickel West assets (409) 119 (290)
Repeal of Minerals Resource Rent Tax legislation(a) – (698) (698)
Total (3,196) 250 (2,946)
(a) Includes amounts attributable to non-controlling interests of US$(12) million.
4. Interests in associates and joint venture entities
The Group’s major shareholdings in associates and joint venture entities, including their (loss)/profit, are
listed below:
Ownership interest at BHP (Loss)/profit from equity accounted
Billiton Group reporting date(a) investments and related impairments
31 Dec 31 Dec 30 June Half year ended Half year ended Year ended
2015 2014 2015 31 Dec 2015 31 Dec 2014 30 June 2015
% % % US$M US$M US$M
Restated
Share of operating (loss)/profit of
equity accounted investments:
Carbones del Cerrejon LLC 33.33 33.33 33.33 (29) (24) (20)
Compañia Minera Antamina SA 33.75 33.75 33.75 94 156 229
Samarco Mineração SA(b) 50 50 50 (519) 216 371
Other (16) (13) (32)
Share of operating (loss)/profit of equity accounted investments (470) 335 548
Impairment of Samarco Mineração SA(c) (525) – –
(Loss)/profit from equity accounted investments and related
impairments (995) 335 548
(a) The ownership interest at the Group’s and the associates and joint venture entities’ reporting dates are the same.
(b) Refer to note 9 Significant events for further information regarding the financial impact of the Samarco dam failure in November
2015 on BHP Billiton’s share of Samarco’s operating profit. US$(519) million includes exceptional items of US$(655) million
share of loss relating to the Samarco dam failure and US$136 million share of operating profit prior to the dam failure.
(c) Includes exceptional item of US$(525) million. Refer to note 9 Significant events for information regarding the financial impact
of the Samarco dam failure in November 2015 on BHP Billiton’s share of Samarco’s operating profit.
5. Net finance costs
Half year ended
Half year ended 31 Dec 2014 Year ended
31 Dec 2015 US$M 30 June 2015
US$M Restated US$M
Financial expenses
Interest on bank loans and overdrafts 1 6 9
Interest on all other borrowings(a) 436 228 517
Discounting on provisions and other liabilities 168 179 333
Net interest expense on post-retirement employee benefits 8 7 15
Finance lease and hire purchase interest 7 12 25
Fair value change on hedged loans 82 869 372
Fair value change on hedging derivatives (127) (874) (358)
Interest capitalised(b) (56) (83) (148)
Exchange variations on net debt(c) (27) (69) (63)
492 275 702
Financial income
Interest income (63) (41) (88)
Net finance costs 429 234 614
(a) Interest on all other borrowings in the half year ended 31 December 2014 and year ended 30 June 2015 included net interest
income of US$67 million with respect to Petrohawk Senior Notes, which included gains of US$80 million on the early
redemption of notes in August 2014.
(b) Interest has been capitalised at the rate of interest applicable to the specific borrowings financing the assets under construction
or, where financed through general borrowings, at a capitalisation rate representing the average interest rate on such
borrowings. For the half year ended 31 December 2015, the capitalisation rate was 2.36 per cent (31 December 2014: 1.89 per
cent; 30 June 2015: 1.94 per cent).
(c) Exchange variations on net debt in the half year ended 31 December 2015 predominantly comprises revaluations of US$17
million on non-USD finance leases (31 December 2014: US$60 million; 30 June 2015: US$109 million).
6. Earnings per share
Half year ended 31 December 2015 Continuing Discontinued Total
operations operations
Basic loss per ordinary share (US cents) (106.5) – (106.5)
Diluted loss per ordinary share (US cents) (106.2) – (106.2)
Basic loss per American Depositary Share (ADS) (US cents)(a) (213.0) – (213.0)
Diluted loss per American Depositary Share (ADS) (US cents)(a) (212.4) – (212.4)
Basic loss (US$M) (5,669) – (5,669)
Diluted loss (US$M) (5,669) – (5,669)
Half year ended 31 December 2014 Continuing Discontinued Total
Restated operations operations
Basic earnings per ordinary share (US cents) 73.6 6.6 80.2
Diluted earnings per ordinary share (US cents) 73.4 6.6 80.0
Basic earnings per American Depositary Share (ADS) (US cents)(a) 147.2 13.2 160.4
Diluted earnings per American Depositary Share (ADS) (US cents)(a) 146.8 13.2 160.0
Basic earnings (US$M) 3,914 351 4,265
Diluted earnings (US$M) 3,914 351 4,265
Year ended 30 June 2015 Continuing Discontinued Total
operations operations
Basic earnings/(loss) per ordinary share (US cents) 65.5 (29.6) 35.9
Diluted earnings/(loss) per ordinary share (US cents) 65.3 (29.5) 35.8
Basic earnings/(loss) per American Depositary Share (ADS) (US cents)(a) 131.0 (59.2) 71.8
Diluted earnings/(loss) per American Depositary Share (ADS) (US cents)(a) 130.6 (59.0) 71.6
Basic earnings/(loss) (US$M) 3,483 (1,573) 1,910
Diluted earnings/(loss) (US$M) 3,483 (1,573) 1,910
(a) Each American Depositary Share represents two ordinary shares.
The weighted average number of shares used for the purposes of calculating diluted earnings per share
reconciles to the number used to calculate basic earnings per share as follows:
Half year ended Half year ended Year ended
31 Dec 2015 31 Dec 2014 30 June 2015
Million Million Million
Weighted average number of shares
Basic earnings per ordinary share denominator 5,322 5,317 5,318
Shares and options contingently issuable under employee
share ownership plans 15 17 15
Diluted earnings per ordinary share denominator 5,337 5,334 5,333
7. Dividends
Half year ended Half year ended Year ended
31 Dec 2015 31 Dec 2014 30 June 2015
US cents US$M US cents US$M US cents US$M
Dividends paid during the period (per
share)(a)
Prior year final dividend 62.0 3,299 62.0 3,392 62.0 3,292
Interim dividend N/A – N/A – 62.0 3,304
62.0 3,299 62.0 3,392 124.0 6,596
Dividends determined in respect of the
period (per share)(a)
Interim dividend 16.0 854 62.0 3,298 62.0 3,298
Final dividend N/A – N/A – 62.0 3,301
16.0 854 62.0 3,298 124.0 6,599
(a) Includes 5.5 per cent dividend on 50,000 BHP Billiton Plc preference shares of £1 each determined and paid annually (31
December 2014: 5.5 per cent; 30 June 2015: 5.5 per cent).
Subsequent to the half year ended 31 December 2015, on 23 February 2016, BHP Billiton determined an
interim dividend referred to in the table above, which will be paid on 31 March 2016.
Each American Depositary Share (ADS) represents two ordinary shares of BHP Billiton Limited or BHP
Billiton Plc. Dividends determined on each ADS represent twice the dividend determined on BHP Billiton
ordinary shares.
BHP Billiton Limited dividends for all periods presented are, or will be, fully franked based on a tax rate of
30 per cent.
8. Financial risk management – Fair values
All financial assets and financial liabilities, other than derivatives, are initially recognised at the fair value of
consideration paid or received, net of transaction costs as appropriate, and subsequently carried at fair
value or amortised cost, as indicated in the tables below. Derivatives are initially recognised at fair value on
the date the contract is entered into and are subsequently remeasured at their fair value.
The financial assets and liabilities are presented by class in the tables below at their carrying values, which
generally approximate to fair value. In the case of US$3,320 million (30 June 2015: US$3,321 million) of
fixed rate debt not swapped to floating rate, the fair value at 31 December 2015 was US$3,148 million (30
June 2015: US$3,538 million).
Financial assets and liabilities
31 December 2015 Other
Held at financial
fair value assets and
Available through Cash liabilities at
Loans and for sale profit or flow amortised
receivables securities loss hedges cost Total
US$M US$M US$M US$M US$M US$M
Financial assets
Cash and cash equivalents 10,626 – – – – 10,626
Trade and other receivables(a) 2,265 – 682 – – 2,947
Cross currency and interest rate swaps – – 863 8 – 871
Other derivative contracts – – 312 – – 312
Loans to equity accounted investments 903 – – – – 903
Shares – 18 – – – 18
Other investments – 1 54 – – 55
Total financial assets 13,794 19 1,911 8 – 15,732
Non-financial assets 102,937
Total assets 118,669
Financial liabilities
Trade and other payables(b) – – 376 – 4,794 5,170
Cross currency and interest rate swaps – – (24) 1,873 – 1,849
Commodity contracts – – 4 – – 4
Other derivative contracts – – 12 – – 12
Bank overdrafts and short-term borrowings(c) – – – – 45 45
Bank loans(c) – – – – 2,132 2,132
Notes and debentures(c) – – – – 33,835 33,835
Finance leases(c) – – – – 362 362
Other(c) – – – – 173 173
Total financial liabilities – – 368 1,873 41,341 43,582
Non-financial liabilities 13,657
Total liabilities 57,239
8. Financial risk management – Fair values (continued)
Financial assets and liabilities
Other
30 June 2015 Held at financial
fair value assets and
Available through Cash liabilities at
Loans and for sale profit or flow amortised
receivables securities loss hedges cost Total
US$M US$M US$M US$M US$M US$M
Financial assets
Cash and cash equivalents 6,753 – – – – 6,753
Trade and other receivables(a) 3,534 – 952 – – 4,486
Cross currency and interest rate swaps – – 858 134 – 992
Forward exchange contracts – – 1 – – 1
Commodity contracts – – 6 – – 6
Other derivative contracts – – 221 – – 221
Loans to equity accounted investments 995 – – – – 995
Shares – 21 – – – 21
Other investments – 1 – – – 1
Total financial assets 11,282 22 2,038 134 – 13,476
Non-financial assets 111,104
Total assets 124,580
Financial liabilities
Trade and other payables(b) – – 176 – 6,660 6,836
Cross currency and interest rate swaps – – (62) 1,329 – 1,267
Commodity contracts – – 4 – – 4
Other derivative contracts – – 11 – – 11
Bank overdrafts and short-term borrowings(c) – – – – 140 140
Bank loans(c) – – – – 1,595 1,595
Notes and debentures(c) – – – – 28,725 28,725
Finance leases(c) – – – – 438 438
Other(c) – – – – 272 272
Total financial liabilities – – 129 1,329 37,830 39,288
Non-financial liabilities 14,747
Total liabilities 54,035
(a) Excludes input taxes of US$349 million (30 June 2015: US$339 million) included in other receivables.
(b) Excludes input taxes of US$530 million (30 June 2015: US$582 million) included in other payables.
(c) All risk bearing liabilities, excluding finance leases, are unsecured.
8. Financial risk management – Fair values (continued)
Fair value hierarchy
The carrying amount of financial assets and liabilities measured at fair value is where possible, calculated
with reference to quoted prices in active markets for identical assets or liabilities. Where no price
information is available from a quoted market source, alternative market mechanisms or recent comparable
transactions, fair value is estimated based on the Group’s views on relevant future prices, net of valuation
allowances to accommodate liquidity, modelling and other risks implicit in such estimates. The inputs used
in fair value calculations are determined by the relevant Group Function. Our Group Functions support the
Businesses and operate under a defined set of accountabilities authorised by the Group Management
Committee (GMC). Movements in the fair value of financial assets and liabilities may be recognised through
the income statement or in other comprehensive income. The following table shows the Group’s financial
assets and liabilities carried at fair value with reference to the nature of valuation inputs used.
31 December 2015 Level 1(a) Level 2(b) Level 3(c) Total
US$M US$M US$M US$M
Financial assets and liabilities
Trade and other receivables – 682 – 682
Trade and other payables – (376) – (376)
Cross currency and interest rate swaps – (978) – (978)
Commodity contracts – (4) – (4)
Other derivative contracts – (5) 305 300
Investments(d) 55 – 18 73
Total 55 (681) 323 (303)
30 June 2015 Level 1(a) Level 2(b) Level 3(c) Total
US$M US$M US$M US$M
Financial assets and liabilities
Trade and other receivables – 952 – 952
Trade and other payables – (176) – (176)
Cross currency and interest rate swaps – (275) – (275)
Forward exchange contracts – 1 – 1
Commodity contracts – 2 – 2
Other derivative contracts – 12 198 210
Investments(d) 1 – 21 22
Total 1 516 219 736
(a) Valuation is based on unadjusted quoted prices in active markets for identical financial assets and liabilities.
(b) Valuation is based on inputs (other than quoted prices included in level 1) that are observable for the financial asset or liability,
either directly (i.e. as unquoted prices) or indirectly (i.e. derived from prices).
(c) Valuation is based on inputs that are not based on observable market data.
(d) Includes shares and other investments.
8. Financial risk management – Fair values (continued)
Level 3 financial assets and liabilities
The following table shows the movements in the Group’s level 3 financial assets and liabilities.
Half year ended Year ended
31 Dec 2015 30 June 2015
US$M US$M
At the beginning of the financial period 219 754
Additions – 16
Disposals – (407)
Realised gains recognised in the income statement(a) 1 9
Unrealised gains recognised in the income statement(a) 106 33
Unrealised losses recognised in other comprehensive income(b) (3) (9)
Impairment – (15)
Transfers – (162)
Total at the end of the financial period 323 219
(a) Realised and unrealised gains and losses recognised in the income statement are recorded in expenses.
(b) Unrealised gains and losses recognised in other comprehensive income are recorded in the financial assets reserve.
Sensitivity of level 3 financial assets and liabilities
The carrying amount of financial assets and liabilities that are valued using inputs other than observable
market data are calculated using appropriate valuation models, including discounted cash flow modelling,
with inputs such as commodity prices, foreign exchange rates and inflation. The potential effect of using
reasonably possible alternative assumptions in these models, based on a change in the most significant
input by 10 per cent while holding all other variables constant, is shown in the following table. Significant
inputs are assessed individually for each financial asset and liability.
Half year ended 31 December 2015 Profit after taxation Equity
10 per 10 per 10 per 10 per
cent cent cent cent
Carrying increase decrease increase decrease
amount in input in input in input in input
US$M US$M US$M US$M US$M
Financial assets and liabilities
Other derivative contracts 305 44 (44) 44 (44)
Investments 18 – – 2 (2)
Total 323 44 (44) 46 (46)
Year ended 30 June 2015 Profit after taxation Equity
10 per 10 per 10 per 10 per
cent cent cent cent
Carrying increase decrease increase decrease
value in input in input in input in input
US$M US$M US$M US$M US$M
Financial assets and liabilities
Other derivative contracts 198 45 (45) 45 (45)
Investments 21 – – 2 (2)
Total 219 45 (45) 47 (47)
9. Significant events – Samarco dam failure
On 5 November 2015, the Samarco Mineração S.A (Samarco) iron ore operation in Minas Gerais, Brazil
experienced a tailings dam failure that resulted in a release of mine tailings, flooding the community of
Bento Rodrigues and impacting other communities downstream (the Samarco dam failure). Refer to pages
2 and 3 for further details.
Samarco is jointly owned by BHP Billiton Brasil Limitada (BHP Billiton Brasil) and Vale S.A (Vale). BHP
Billiton Brasil’s 50% interest is accounted for as an equity accounted joint venture investment. BHP Billiton
Brasil does not separately recognise its share of the underlying assets and liabilities of Samarco, but
instead records the investment as one line on the balance sheet. Accordingly, for any charges recognised
by Samarco, BHP Billiton Brasil and therefore the Group recognise 50% of this expense when adjusting the
carrying value of the investment for the BHP Billiton share of Samarco’s profit or loss. Any charges incurred
directly by BHP Billiton Brasil or other BHP Billiton entities are recognised 100% in the Group’s results.
The financial impacts of the Samarco dam failure on the Group’s income statement, balance sheet and
cash flow statement for the half year ended 31 December 2015 are shown in the table below and have
been treated as an exceptional item. These do not include BHP Billiton Brasil’s share of the results of
Samarco prior to the Samarco dam failure, which is disclosed in the note 4 Interests in associates and joint
venture entities.
Half year ended
31 December 2015
US$M
Income statement
Expenses excluding net finance costs
- Costs incurred directly by BHP Billiton in relation to the Samarco dam failure (8)
(Loss)/profit from equity accounted investments and related impairments
- Share of loss relating to the Samarco dam failure (655)
- Impairment of the carrying value of the investment in Samarco (525)
Loss before taxation (1,188)
Income tax benefit 330
Loss after taxation (858)
Balance sheet
Trade and other payables (5)
Investments accounted for using the equity method (1,180)
Deferred tax liabilities 330
Net assets/(liabilities) (855)
Cash flow statement
Loss before taxation (1,188)
Comprising:
Costs incurred directly by BHP Billiton in relation to the Samarco dam failure (8)
Share of loss relating to the Samarco dam failure (655)
Impairment of the carrying value of the investment in Samarco (525)
Non-cash items 1,185
Net operating cash flows (3)
9. Significant events – Samarco dam failure (continued)
Equity accounted investment in Samarco
The following table details the movement in the carrying value of BHP Billiton Brasil’s equity accounted
investment in Samarco:
Half year ended 31 December 2015
US$M
At the beginning of the reporting period 1,044
Share of operating profit prior to the Samarco dam failure 136
Share of loss relating to the Samarco dam failure (655)
Impairment of the carrying value of the investment in Samarco (525)
(Loss)/profit from equity accounted investments and related impairments (1,044)
Investment -
Dividends received -
At the end of the reporting period -
Subsequent to recognising the Group’s share of Samarco’s loss, the Group has assessed the recoverability
of its investment in light of uncertainties surrounding the nature and timing of ongoing future operations. As
a result, an impairment charge of US$525 million was recognised in the half year ended 31 December
2015.
Funding
Under the terms of the joint venture agreement, BHP Billiton Brasil does not have an existing obligation to
fund Samarco. To date, no requests for funding or future investment have been received. Any future
investment would be subject to a future decision and be accounted for at that time.
Contingencies
BHP Billiton Brasil contingencies
As at 31 December 2015 BHP Billiton Brasil has identified contingent liabilities arising as a consequence of
the Samarco dam failure as follows:
Environment and socio-economic rehabilitation
Rio Doce Fund
On Friday 27 November 2015, BHP Billiton and Vale announced plans to work, together with Samarco, to
establish a voluntary, non-profit fund to support the recuperation of the Rio Doce river system, affected by
the Samarco dam failure. Until such time as BHP Billiton and Vale determine the extent of the commitment
to this voluntary fund, it is not possible to arrive at a range of outcomes or a reliable estimate of the
commitment and therefore a provision has not been recognised and nor has any contingent liability been
quantified.
Legal
BHP Billiton Brasil is among the companies named as defendants in legal proceedings initiated by
individuals, non-governmental organisations (NGOs), corporations and governmental entities in Brazilian
federal and state courts following the Samarco dam failure. The other defendants include Vale S.A. and
Samarco. The lawsuits include claims for compensation, environmental rehabilitation and violations of
Brazilian environmental and other laws, among other matters. The lawsuits seek various remedies,
including rehabilitation costs, compensation to injured individuals and families of the deceased, recovery of
personal and property losses and injunctive relief.
In addition, government inquiries and investigations relating to the Samarco dam failure have been
commenced by numerous agencies of the Brazilian government.
9. Significant events – Samarco dam failure (continued)
Among the claims brought against BHP Billiton Brasil, is a Public Civil Claim commenced by the Federal
Attorney General, States of Espirito Santo, Minas Gerais and other public authorities on 30 November
2015, seeking the establishment of a fund of up to R$20 billion (US$5.1 billion) in aggregate for clean-up
costs and damages. BHP Billiton Brasil, Samarco and Vale S.A. are currently in negotiations with the
Brazilian government in relation to this claim. Given the preliminary status of these negotiations, it is not
possible at this time to provide a range of possible outcomes or a reliable estimate of potential future
exposures for BHP Billiton Brasil in relation to the R$20 billion (US$5.1 billion) claim.
Additional lawsuits and government investigations relating to the Samarco dam failure may be brought
against BHP Billiton Brasil and possibly other BHP Billiton entities in Brazil or other jurisdictions.
BHP Billiton’s potential liabilities resulting from other pending and future claims, lawsuits and enforcement
actions relating to the Samarco dam failure, together with the potential cost of implementing remedies
sought in the various proceedings, cannot be reliably estimated at this time and therefore a provision has
not been recognised and nor has any contingent liability been quantified. Ultimately these could have a
material adverse impact on BHP Billiton’s business, competitive position, cash flows, prospects, liquidity
and shareholder returns.
Samarco contingencies
Environment and socio-economic rehabilitation
As at 31 December 2015, Samarco has recognised provisions based on currently available information.
Samarco has indicated that it anticipates that it will incur future costs beyond those provisioned. The
magnitude, scope and timing of costs related to the Samarco dam failure are subject to a very high degree
of uncertainty, primarily due to immaturity of the environmental and socio-economic impact assessments,
as well as approval of rehabilitation scope and ongoing activities of regulators and other government
authorities. These uncertainties are likely to continue for a significant period. Any such unrecognised
obligations are therefore contingent liabilities and, at present, it is not practicable to estimate their
magnitude or possible timing of payment. Accordingly, it is also not possible to provide a range of possible
outcomes or a reliable estimate of total potential future exposures at this time.
As the assessment of damage progresses, changes to key assumptions could result in a material change
to the amount of the provision in future reporting periods.
Legal
Samarco has been named as a defendant in numerous lawsuits resulting from the Samarco dam failure.
These lawsuits have been brought by individuals, corporations, NGOs and governmental entities seeking
damages for, among other matters, personal injury, wrongful death, commercial or economic injury, breach
of contract and violations of statutes.
In addition, government investigations of the Samarco dam failure by numerous agencies of the Brazilian
government have commenced.
As noted above, amongst the claims brought against Samarco is a Public Civil Claim commenced by the
Federal Attorney General, States of Espirito Santo, Minas Gerais and other public authorities on 30
November 2015, seeking the establishment of a fund of up to R$20 billion (US$5.1 billion) in aggregate for
clean-up costs and damages. BHP Billiton Brasil, Samarco and Vale S.A. are currently in negotiations with
the Brazilian government in relation to this claim. Given the preliminary status of these negotiations, it is not
possible at this time to provide a range of possible outcomes or a reliable estimate of potential future
exposures for Samarco in relation to the R$20 billion (US$5.1 billion) claim.
Other pending lawsuits and investigations are at the early stages of proceedings.
9. Significant events – Samarco dam failure (continued)
Until further facts are developed; court rulings clarify the issues in dispute, liability and damages; trial
activity nears, or other actions such as possible settlements occur, it is not possible to arrive at a range of
outcomes or a reliable estimate of Samarco’s obligations arising from these matters and therefore Samarco
has not recognised a provision or quantified a contingent liability. Additional claims may be brought against
Samarco. A provision has not been made by Samarco for claims yet to be filed. Given the significant
uncertainties surrounding possible outcomes it is not possible for Samarco to arrive at a range of outcomes
or a reliable estimate of the liability for any unfiled claims.
Insurance
BHP Billiton Insurance
BHP Billiton has third party liability insurance for claims related to the Samarco dam failure made directly
against BHP Billiton Brasil or other BHP Billiton entities. Such claims may be externally insured up to
US$360 million (when adjusted for BHP Billiton Brasil’s interest in Samarco). External insurers have been
advised of the Samarco dam failure although no formal claim has currently been made under the policy. At
31 December 2015 an insurance receivable has not been recognised for any potential recoveries under
insurance arrangements.
Samarco Insurance
Samarco has standalone insurance policies in place with Brazilian and global insurers. Samarco has
notified insurers including those covering property, project and liability risks. Insurers have appointed loss
adjusters or claims representatives to investigate and assist with the claims process. Given the adjustment
process for all policies is at an early stage with the extent of coverage yet to be agreed, an insurance
receivable has not been recognised by Samarco for any recoveries under insurance arrangements at 31
December 2015.
10. Subsequent events
Other than the matters outlined elsewhere in this financial information, no matters or circumstances have
arisen since the end of the half year that have significantly affected, or may significantly affect, the
operations, results of operations or state of affairs of the Group in subsequent accounting periods.
Directors’ Report
The Directors present their report together with the half year financial statements for the half year ended 31
December 2015 and the auditor’s review report thereon.
Review of Operations
A detailed review of the Group’s operations, the results of those operations during the half year ended 31
December 2015 and likely future developments are given on pages 1 to 27. The Review of Operations has
been incorporated into, and forms part of, this Directors’ Report.
Principal Risks and Uncertainties
Because of the international scope of the Group's operations and the industries in which it is engaged,
there are a number of risk factors and uncertainties which could have an effect on the Group's results and
operations. Material risks that could impact on the Group's performance include those referred to in the
‘Outlook’ section as well as:
- Fluctuations in commodity prices and impacts of - The commercial counterparties we transact with
ongoing global economic volatility may negatively may not meet their obligations, which may
affect our results, including cash flows and asset negatively impact our results
values
- Our financial results may be negatively affected by - Cost pressures and reduced productivity could
currency exchange rate fluctuations negatively impact our operating margins and
expansion plans
- Reduction in Chinese demand may negatively - Unexpected natural and operational catastrophes
impact our results may adversely impact our operations
- Actions by governments or political events in the - Our non-operated assets may not comply with our
countries in which we operate could have a standards
negative impact on our business
- Failure to discover or acquire new resources, - Breaches in our information technology security
maintain reserves or develop new operations could processes may adversely impact our business
negatively affect our future results and financial activities
condition
- Potential changes to our portfolio of assets through - Safety, health, environmental and community
acquisition and divestments or demerger may have impacts, incidents or accidents and related
a material adverse effect on our future results and regulations may adversely affect our people,
financial condition operations and reputation or licence to operate
- Increased costs and schedule delays may - Climate change may impact the value of our
adversely affect our development projects Company, and our operations and markets
- If our liquidity and cash flow deteriorate significantly - A breach of our governance processes may lead to
it could adversely affect our ability to fund our major regulatory penalties and loss of reputation
capital programs
- We may not fully recover our investments in mining,
oil and gas assets, which may require financial
write-downs
Further information on the above risks and uncertainties can be found on pages 20 to 24 of the Group's
Annual Report for the year ended 30 June 2015, a copy of which is available on the Group's website at
www.bhpbilliton.com.
Dividend
Full details of dividends are given on page 10.
Board of Directors
The Directors of BHP Billiton at any time during or since the end of the half year are:
Jac Nasser – Chairman since March 2010 (a Director since June 2006)
Andrew Mackenzie – an Executive Director since May 2013
Malcolm Brinded – a Director since April 2014
Malcolm Broomhead – a Director since March 2010
Sir John Buchanan – a Director from February 2003 to July 2015
Carlos Cordeiro – a Director from February 2005 to November 2015
Pat Davies – a Director since June 2012
Anita Frew – a Director since September 2015
Carolyn Hewson – a Director since March 2010
Lindsay Maxsted – a Director since March 2011
Wayne Murdy – a Director since June 2009
John Schubert – a Director since June 2000
Shriti Vadera – a Director since January 2011
Auditor’s independence declaration
KPMG in Australia are the auditors of BHP Billiton Limited. Their auditor’s independence declaration under
Section 307C of the Australian Corporations Act 2001 is set out on page 54 and forms part of this Directors’
Report.
Rounding of amounts
BHP Billiton Limited is a company of a kind referred to in Australian Securities and Investments
Commission Class Order No 98/100, dated 10 July 1998. Amounts in the Directors’ Report and half year
financial statements have been rounded to the nearest million dollars in accordance with that Class Order.
Signed in accordance with a resolution of the Board of Directors.
Jac Nasser AO – Chairman
Andrew Mackenzie – Chief Executive Officer
Dated this 23rd day of February 2016
Directors’ Declaration of Responsibility
The half year financial report is the responsibility of, and has been approved by, the Directors. In
accordance with a resolution of the Directors of BHP Billiton, the Directors declare that:
(a) in the Directors’ opinion and to the best of their knowledge, the half year financial statements and
notes, set out on pages 29 to 50, have been prepared in accordance with IAS 34 ‘Interim Financial
Reporting’ as issued by the IASB, IAS 34 ‘Interim Financial Reporting’ as adopted by the EU, AASB
134 ‘Interim Financial Reporting’ as issued by the AASB, the Disclosure and Transparency Rules of the
Financial Conduct Authority in the United Kingdom and the Australian Corporations Act 2001, including:
(i) complying with applicable accounting standards and the Australian Corporations Regulations
2001; and
(ii)giving a true and fair view of the financial position of the BHP Billiton Group as at 31 December
2015 and of its performance for the half year ended on that date;
(b) to the best of the Directors’ knowledge, the Directors’ Report, which incorporates the Review of
Operations on pages 1 to 27, includes a fair review of the information required by:
(i) DTR4.2.7R of the Disclosure and Transparency Rules in the United Kingdom, being an indication
of important events during the first six months of the current financial year and their impact on the
half year financial statements, and a description of the principal risks and uncertainties for the
remaining six months of the year; and
(ii)DTR4.2.8R of the Disclosure and Transparency Rules in the United Kingdom, being related party
transactions that have taken place in the first six months of the current financial year and that
have materially affected the financial position or performance of the BHP Billiton Group during
that period, and any changes in the related party transactions described in the last annual report
that could have such a material effect; and
(c) in the Directors’ opinion, there are reasonable grounds to believe that each of BHP Billiton Limited and
BHP Billiton Plc will be able to pay its debts as and when they become due and payable.
Signed on behalf of the Directors in accordance with a resolution of the Board of Directors.
Jac Nasser AO – Chairman
Andrew Mackenzie – Chief Executive Officer
Dated this 23rd day of February 2016
Lead Auditor’s Independence Declaration under Section 307C of the Corporations Act 2001
To: the Directors of BHP Billiton Limited:
I declare that, to the best of my knowledge and belief, in relation to the review for the half year ended 31
December 2015 there have been:
i. no contraventions of the auditor independence requirements as set out in the Australian
Corporations Act 2001 in relation to the review; and
ii. no contraventions of any applicable code of professional conduct in relation to the review.
This declaration is in respect of BHP Billiton and the entities it controlled during the financial period.
KPMG
Anthony Young
Partner
Melbourne
23 February 2016
KPMG, an Australian partnership and KPMG LLP, a UK limited liability partnership, are member firms of the
KPMG network of independent member firms affiliated with KPMG International Cooperative (‘KPMG
International’), a Swiss entity.
KPMG Australia’s liability limited by a scheme approved under Professional Standards Legislation.
Independent Review Report
Independent Review Report of KPMG LLP (“KPMG UK”) to BHP Billiton Plc and KPMG (“KPMG
Australia”) to the Members of BHP Billiton Limited
Introduction
For the purposes of these reports, the terms “we” and “our” denote KPMG UK in relation to its
responsibilities under its terms of engagement to report to BHP Billiton Plc and KPMG Australia in relation
to Australian professional and regulatory responsibilities and reporting obligations to the members of BHP
Billiton Limited.
The BHP Billiton Group (“the Group”) consists of BHP Billiton Plc and BHP Billiton Limited and the entities
they controlled at the end of the half year or from time to time during the half year ended 31 December
2015.
We have reviewed the condensed half year financial statements of the Group for the half year ended 31
December 2015 (“half year financial statements”), set out on pages 29 to 50, which comprise the
consolidated income statement, consolidated statement of comprehensive income, consolidated balance
sheet, consolidated cash flow statement, consolidated statement of changes in equity, summary of
significant accounting policies and other explanatory notes 1 to 10. We have read the other information
contained in the half year financial report and considered whether it contains any apparent misstatements
or material inconsistencies with the information in the half year financial statements. KPMG Australia has
also reviewed the directors’ declaration set out on page 53 in relation to Australian regulatory requirements
contained in section (a) and (c) of the directors’ declaration.
Directors’ Responsibilities
The half year financial report is the responsibility of, and has been approved by, the Directors. The
Directors are responsible for preparing the half year financial report:
• in accordance with the Disclosure and Transparency Rules (“the DTR”) of the United Kingdom’s
Financial Conduct Authority (“the UK FCA”), and under those rules, in accordance with IAS 34
Interim Financial Reporting as adopted by the European Union; and
• in accordance with Australian Accounting Standards and the Corporations Act 2001. This
responsibility includes establishing and maintaining internal control relevant to the preparation and
fair presentation of the half year financial statements that are free from material misstatement,
whether due to fraud or error; selecting and applying appropriate accounting policies; and making
accounting estimates that are reasonable in the circumstances.
Respective Responsibilities of KPMG UK and KPMG Australia
KPMG UK’s report is made solely to BHP Billiton Plc in accordance with the terms of KPMG UK’s
engagement to assist BHP Billiton Plc in meeting the requirements of the DTR of the UK FCA. KPMG UK’s
review has been undertaken so that it might state to BHP Billiton Plc those matters it is required to state to
it in this report and for no other purpose. To the fullest extent permitted by law, KPMG UK does not accept
or assume responsibility to anyone other than BHP Billiton Plc, for KPMG UK’s review work, for this report,
or for the conclusions it has reached.
KPMG Australia has performed an independent review of the half year financial statements and directors’
declaration in order to state whether, on the basis of the procedures described, it has become aware of any
matter that makes KPMG Australia believe that the half year financial statements and directors’ declaration
are not in accordance with the Corporations Act 2001 including: giving a true and fair view of the Group’s
financial position as at 31 December 2015 and its performance for the half year ended on that date; and
complying with Australian Accounting Standard AASB 134 Interim Financial Reporting and the Australian
Corporations Regulations 2001.
Our responsibility is to express a conclusion on the half year financial statements in the half year financial
report based on our review.
Scope of Review
KPMG UK conducted its review in accordance with International Standard on Review Engagements (UK
and Ireland) 2410 Review of Interim Financial Information Performed by the Independent Auditor of the
Entity issued by the Auditing Practices Board for use in the United Kingdom.
KPMG Australia conducted its review in accordance with Auditing Standard on Review Engagements
ASRE 2410 Review of a Financial Report Performed by the Independent Auditor of the Entity as issued by
the Australian Auditing and Assurance Standards Board. As auditor of BHP Billiton Limited, KPMG
Australia is required by ASRE 2410 to comply with the ethical requirements relevant to the audit of the
annual financial report.
A review of half year financial statements consists of making enquiries, primarily of persons responsible for
financial and accounting matters, and applying analytical and other review procedures. A review is
substantially less in scope than an audit conducted in accordance with auditing standards and
consequently does not enable us to obtain assurance that we would become aware of all significant
matters that might be identified in an audit. Accordingly, we do not express an audit opinion.
Independence
In conducting its review, KPMG Australia has complied with the independence requirements of the
Australian Corporations Act 2001.
Review conclusion by KPMG UK
Based on our review, nothing has come to our attention that causes us to believe that the condensed half
year financial statements in the half year financial report for the six months ended 31 December 2015 are
not prepared, in all material respects, in accordance with IAS 34 Interim Financial Reporting, as adopted by
the EU, and the DTR of the UK FCA.
Stephen Oxley
Partner
For and on behalf of KPMG LLP
Chartered Accountants
London
23 February 2016
Review conclusion by KPMG Australia
Based on our review, which is not an audit, we have not become aware of any matter that makes us
believe that the condensed half year financial statements and directors’ declaration of the Group are not in
accordance with the Australian Corporations Act 2001, including:
a) giving a true and fair view of the Group’s financial position as at 31 December 2015 and of its
performance for the half year ended on that date; and
b) complying with Australian Accounting Standard AASB 134 Interim Financial Reporting and the
Australian Corporations Regulations 2001.
KPMG
Anthony Young
Partner
Melbourne
23 February 2016
KPMG, an Australian partnership and KPMG LLP, a UK limited liability partnership, are member firms of the
KPMG network of independent member firms affiliated with KPMG International Cooperative (‘KPMG
International’), a Swiss entity.
KPMG Australia’s liability limited by a scheme approved under Professional Standards Legislation.
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