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BHP Billiton Results for the Year Ended 30 June 2014
BHP Billiton Plc
Registration number 3196209
Registered in England and Wales
Share code: BIL
ISIN: GB0000566504
19 August 2014
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 year ended 30 June 2014
This statement includes the consolidated results of the BHP Billiton Group, comprising BHP Billiton Limited and BHP Billiton
Plc, for the year ended 30 June 2014 compared with the year ended 30 June 2013 and the year ended 30 June 2012.
The results are prepared in accordance with IFRS and are presented in US dollars.
Headline Earnings
In accordance with the JSE Listing Requirements, Headline Earnings is presented below.
Year ended Year ended Year ended
30 June 30 June 30 June
2014 2013 2012
US$M US$M US$M
Earnings attributable to ordinary shareholders 13,832 11,223 15,473
Adjusted for:
Gain on sale of PP&E, Investments and Operations (646) (3,206) (111)
Impairments/(reversal of impairments) 797 5,496 3,734
Recycling of re-measurements from equity to the income statement (692) 72 203
Tax effect of above adjustments 163 (1,073) (1,232)
Subtotal of Adjustments (378) 1,289 2,594
Headline Earnings 13,454 12,512 18,067
Diluted Headline Earnings 13,454 12,512 18,067
Basic earnings per share denominator (millions) 5,321 5,322 5,323
Diluted earnings per share denominator (millions) 5,338 5,340 5,346
Headline Earnings per share (US cents) 252.8 235.1 339.4
Diluted Headline Earnings per share (US cents) 252.0 234.3 338.0
NEWS RELEASE
Release Time IMMEDIATE
Date 19 August 2014
Number 14/14
BHP BILLITON RESULTS FOR THE YEAR ENDED 30 JUNE 2014
• BHP Billiton reported a record low Total Recordable Injury Frequency of 4.2 per million hours
worked and we suffered no fatalities during the period. While this is an encouraging result, our
efforts to protect the health and safety of our people will be unrelenting.
• A significant improvement in productivity underpinned strong financial performance as Underlying
attributable profit(1)(2) increased by 10% to US$13.4 billion. We embedded productivity-led volume
and cost efficiencies(3) of US$2.9 billion, exceeding our target by 61% or US$1.1 billion. This means
we have now delivered more than US$6.6 billion of sustainable productivity-led gains over the last
two years.
• By further improving productivity and reducing our capital and exploration expenditure(4) by 32% to
US$15.2 billion we delivered a substantial US$8.1 billion increase in free cash flow(2), despite
weaker commodity prices. As a result, our balance sheet continued to strengthen and we finished
the period with net debt(2) of US$25.8 billion.
• We have also announced plans to create an independent global metals and mining company via a
demerger. With a simpler portfolio(5), we are targeting at least another US$3.5 billion of
productivity-related gains(6) by the end of the 2017 financial year.
• Capital and exploration expenditure(4) is expected to decline to approximately US$14.8 billion in the
2015 financial year and be no more than US$14 billion should the proposed demerger be
implemented. By maintaining an internal focus and concentrating investment in our major basins we
believe an average rate of return of greater than 20% is achievable for our favoured development
options.
• With robust volume growth and further productivity gains expected, we remain confident in the
outlook for the Group. On this basis, we increased our full-year progressive base dividend by 4% to
121 US cents per share for an Underlying payout ratio(7) of 48%. We will seek to steadily increase or
at least maintain the dividend per share in US dollar terms at each half-yearly payment following the
demerger, implying a higher payout ratio.
• We will return excess cash to shareholders in the most efficient way. By ensuring that we start from
a position of strength, we will be well placed to implement an enduring program that can be
managed in a more consistent and predictable manner.
Year ended 30 June 2014 2013 Change
US$M US$M %
Profit from operations (EBIT) 23,412 21,002 11.5%
Attributable profit 13,832 11,223 23.2%
Basic earnings per share (cents) 260.0 210.9 23.3%
Dividend per share (cents) 121.0 116.0 4.3%
Net operating cash flow 25,364 20,154 25.9%
Underlying EBITDA(1) 32,359 30,308 6.8%
Underlying EBIT(1) 22,861 22,930 (0.3%)
Underlying attributable profit 13,447 12,208 10.1%
Underlying basic earnings per share (cents)(2) 252.7 229.4 10.2%
Capital and exploration expenditure (BHP Billiton share)(4) 15,181 22,291 (31.9%)
Results for the 2014 financial year
BHP Billiton Chief Executive Officer, Andrew Mackenzie, said: “In the last 12 months we have delivered on our
commitments. Our operational performance continued to improve, enabling us to exceed production guidance for
a number of our core commodities including iron ore, metallurgical coal and petroleum liquids. Productivity-led
volume and cost efficiencies(3) of US$2.9 billion were US$1.1 billion ahead of plan, meaning we have now
embedded more than US$6.6 billion of sustainable, annualised productivity-led gains over the last two years.”
He added: “BHP Billiton is becoming a simpler, more productive company and the demerger proposal we have
announced today is an important step forward. We plan to create an independent global metals and mining
company based on a selection of high-quality aluminium, coal, manganese, nickel and silver assets. Separating
these businesses via a demerger has the potential to unlock shareholder value by allowing BHP Billiton to
improve the productivity of its largest businesses more quickly and by creating a new company specifically
designed to enhance the performance of its assets. With a simpler portfolio(5), we are targeting at least another
US$3.5 billion of productivity-related gains(6) by the end of the 2017 financial year.
“Our Iron Ore business clearly illustrates this opportunity. At Western Australia Iron Ore, we now expect the
debottlenecking of our mines and inner harbour infrastructure to increase our supply-chain capacity to 290 Mtpa
(100 per cent basis). The additional 65 Mtpa of capacity is likely to have a capital intensity below US$50 per
annual tonne with the improvement in productivity and economies of scale also expected to significantly reduce
unit costs.
“With robust volume growth and further productivity gains expected, we remain confident in the outlook for the
Group. On this basis, we increased our full-year progressive base dividend by four per cent to 121 US cents per
share for an Underlying payout ratio of 48 per cent. We will seek to steadily increase or at least maintain the
dividend per share in US dollar terms at each half-yearly payment following the demerger, implying a higher
payout ratio.”
He concluded by saying: “The pace at which our balance sheet strengthens will also depend on external factors,
such as commodity prices and foreign exchange rates. As in the past, we will return excess cash to shareholders
in the most efficient way. By ensuring that we start from a position of strength, we will be well placed to implement
an enduring program that can be managed in a more consistent and predictable manner.”
Keeping our people and operations safe
Having our people return home safe and well at the end of every working day is central to the success of our
organisation. BHP Billiton reported a record low Total Recordable Injury Frequency of 4.2 per million hours
worked and we suffered no fatalities during the period. While this is an encouraging result, our efforts to protect
the health and safety of our people will be unrelenting.
Proposed demerger will largely complete our simplification process in a single step
BHP Billiton today said it plans to create an independent global metals and mining company based on a selection
of its high-quality aluminium, coal, manganese, nickel and silver assets. Separating these businesses via a
demerger has the potential to unlock shareholder value by significantly simplifying the Group and creating two
portfolios of complementary assets.
Once simplified, BHP Billiton will be almost exclusively focused on its exceptionally large, long-life iron ore,
copper, coal, petroleum and potash basins. With fewer assets and a greater upstream focus, the Group will be
able to reduce costs and improve the productivity of its largest businesses more quickly. As a result, it is
expected to generate stronger growth in free cash flow and a superior return on investment.
Subject to final Board approval to proceed, shareholder approval and the receipt of satisfactory third party
approvals, the demerger is expected to be completed in the first half of the 2015 calendar year.
Seeking a continual improvement in operating performance
A significant improvement in productivity underpinned a nine per cent increase in Group production(8) during the
2014 financial year with production records achieved at 12 operations and for four commodities. Western
Australia Iron Ore and Queensland Coal production exceeded guidance with both rising by over 20 per cent as
we delivered more tonnes from existing infrastructure and growth projects ahead of schedule. At Escondida, an
increase in mill throughput and concentrator utilisation offset copper grade decline, while our Onshore US
business delivered a 73 per cent increase in petroleum liquids production. We expect to maintain strong
momentum and remain on track to generate Group production(8) growth of 16 per cent over the two years to the
end of the 2015 financial year.
Focusing on the controllable and targeting at least US$3.5 billion of additional productivity-led gains
Underlying EBITDA increased by seven per cent to US$32.4 billion in the 2014 financial year as productivity-led
volume and cost efficiencies(3) of US$2.9 billion were generated during the period. By exceeding this year’s
productivity target by US$1.1 billion or over 60 per cent, we have now embedded more than US$6.6 billion of
sustainable, annualised productivity-related gains(3) over the last two years. With a simpler portfolio(5), we are
targeting at least another US$3.5 billion of productivity-related gains(6) by the end of the 2017 financial year.
Productivity gains FY14 actual(3) FY15-FY17
US$ billion target(6)
Volume efficiencies 1.0 1.2
Controllable cash cost efficiencies 1.9 2.3
Total 2.9 3.5
The successful commissioning and ramp-up of our low-risk, brownfield development projects increased
Underlying EBIT by a further US$1.9 billion, although this was offset by: uncontrollable factors such as
commodity prices and inflation; an increase in our depreciation and amortisation expense; and additional cash
and non-cash items including those in the following table. As a result, Underlying EBIT was unchanged for the
year at US$22.9 billion.
Additional items December 2013 half year 2014 financial year
Underlying Underlying Underlying Underlying
US$ billion EBITDA EBIT EBITDA EBIT
Impairments(i) – (0.1) – (0.8)
Mine site rehabilitation(ii) – – (0.3) (0.3)
Redundancies(iii) – – (0.1) (0.1)
Closure costs(iv) – – (0.2) (0.2)
Other(v) (0.1) (0.1) (0.1) (0.1)
Total (0.1) (0.2) (0.7) (1.5)
(i) Includes impairment charges at Energy Coal South Africa (US$292 million); charges for minor Gulf of Mexico assets
(US$184 million); a charge in our Potash business associated with the Port of Vancouver (US) (US$68 million) and
other minor charges (US$253 million).
(ii) Represents a US$300 million charge related to the revision of mine site rehabilitation provisions for the Group’s North
American closed mines.
(iii) Includes redundancies from restructuring programs in Iron Ore (US$63 million), Coal (US$40 million) and Aluminium,
Manganese and Nickel (US$40 million).
(iv) Includes costs associated with the closure of the Perseverance underground mine (US$21 million) and the cessation of
smelting activities at Bayside (US$135 million).
(v) Includes UK pension plan charges (US$112 million), the profit on sale of Liverpool Bay (US$120 million), the profit on
sale of the Energy Coal South Africa Optimum Coal Purchase agreement (US$84 million) and an adjustment to the
Browse divestment proceeds (US$143 million charge).
Underlying attributable profit increased by 10 per cent to US$13.4 billion in the 2014 financial year, benefitting
from a reduction in the Group’s adjusted effective tax rate(2) to 32.5 per cent. Attributable profit was
US$13.8 billion and included exceptional items of US$385 million (after tax).
Strong growth in free cash flow despite volatile commodity markets
By further improving productivity and reducing our rate of investment we delivered a substantial US$8.1 billion
increase in free cash flow, despite weaker commodity prices. In this context, capital and exploration
expenditure(4) declined by 32 per cent to US$15.2 billion in the period.
As a result, our balance sheet continued to strengthen and we finished the period with net debt of US$25.8 billion
for a gearing ratio of 23 per cent. This includes US$757 million of finance leases that were brought to account in
the June 2014 half year.
With robust volume growth and further productivity gains expected, we remain confident in the outlook for the
Group. On this basis, we have increased our full-year progressive base dividend by four per cent to 121 US cents
per share (December 2013 half year: 59 US cents per share; June 2014 half year: 62 US cents per share). This
equates to an annual distribution of US$6.4 billion which is comfortably covered by free cash flow. In total, we
have now returned US$64 billion in the form of dividends and buy-backs over the last 10 years, equivalent to an
Underlying payout ratio of approximately 50 per cent.
A strong balance sheet and selective investment will enable us to grow value and shareholder returns
Capital and exploration expenditure(4) is expected to decline to approximately US$14.8 billion in the 2015
financial year and be no more than US$14 billion should the proposed demerger be implemented. Our investment
plans will be optimised within this framework to deliver the best results in terms of net present value, internal rate
of return, return on capital employed and operating margin.
At the end of the 2014 financial year, the group had eight major projects under development with a combined
budget of US$14.1 billion. Beyond our current projects in execution, the Group’s opportunity-rich portfolio remains
a key point of differentiation and allows us to maintain an internal focus. As we concentrate investment in our
major basins, fewer projects will pass through our tollgates and prospective investment returns will rise. We
believe that an average rate of return of greater than 20 per cent (ungeared, after tax, nominal dollars) is
achievable for our favoured development options.
These growth options and our broader commitment to improve operating performance will underpin the longer-
term growth of our progressive base dividend. In this context, we will seek to steadily increase or at least maintain
the dividend per share in US dollar terms at each half-yearly payment following the demerger, implying a higher
payout ratio.
The pace at which our balance sheet strengthens will also depend on external factors, such as commodity prices
and foreign exchange rates. As in the past, we will return excess cash to shareholders in the most efficient way.
By ensuring that we start from a position of strength, we will be well placed to implement an enduring program
that can be managed in a more consistent and predictable manner.
Outlook
Economic outlook
The global economy grew at a moderate rate in the 2014 financial year. Momentum in the United States, Japan
and the United Kingdom was underpinned by central bank monetary policy. Europe’s economy improved
marginally, although the recovery was constrained by high levels of unemployment. Emerging markets, including
China, experienced a moderate slowdown.
In a relative sense, the Chinese economy continues to grow strongly with signs that it is rebalancing.
Consumption continued to be supported by higher household incomes while fixed asset investment softened, led
by the property sector, as the central bank restricted access to credit. Rapid credit growth in the non-bank
financial sector remained an important concern for policymakers.
We remain confident in the short to medium-term outlook for the Chinese economy. Measured stimulus recently
introduced by the government demonstrates their commitment to maintain economic growth above seven per
cent. We believe consumption and services will continue to increase in importance, while the market’s role in
allocating capital will be enhanced. Greater transparency within the fiscal system is also expected to reshape the
relationship between central and local government.
The underlying performance of the United States economy continued to improve despite the significant disruption
caused by severe weather in the March 2014 quarter. The curtailment of quantitative easing appears to have had
a limited impact on sentiment as a solid increase in demand reflects a stronger labour market, rising disposable
incomes, and higher equities and housing prices. Business investment has been a weak link in the recovery so
far as companies have responded slowly to better economic conditions, despite higher levels of profitability. An
increase in capital spending will be required to sustain the recovery in the medium term.
The Japanese economy has responded strongly to expansionary monetary and fiscal policy over the past year.
Investment spending and wages increased as corporate profits benefited from the depreciation of the yen, while
an increase in the national sales tax in April had a limited impact on consumption. These factors have increased
the potential for faster growth in the short term, although a longer-term, sustainable recovery will be contingent on
the scale and speed of structural reform.
With regard to the global economy, stronger United States growth and an associated tightening of monetary
policy could result in the rapid outflow of capital from emerging economies. However, developing nations with
sound macroeconomic fundamentals would be less likely to experience a severe impact from this transition.
Commodities
Commodity markets were volatile in the second half of the 2014 financial year.
As anticipated, Chinese crude steel production growth decelerated in response to weakness in the construction
sector. On average, we expect the ratio of Chinese crude steel production growth to underlying GDP growth to
remain below one, although seasonal factors and policy settings will continue to influence short-term output.
Global steel demand growth outside of China is likely to accelerate during the remainder of the 2014 calendar
year.
The supply of steelmaking raw materials has grown more quickly than demand. As predicted, lower-cost
seaborne iron ore supply is increasingly displacing higher-cost Chinese domestic production. As this trend
continues, the cost curve is likely to flatten as high-cost production exits the market. In metallurgical coal, high-
cost, uneconomic supply has remained resilient although we do expect to see an increasing number of
production cuts, particularly in the United States. Given robust underlying demand growth for premium hard
coking coals, pricing for our products is likely to be well supported in the medium and longer term.
Indonesian and Australian exports continue to keep the thermal coal market well supplied, prolonging the weaker
pricing environment. While demand from key importing regions remains steady, prices are unlikely to respond
unless uneconomic supply exits the market.
In copper, robust demand for refined metal, supply disruptions and a shortage of scrap has ensured that the
market remains broadly balanced. We believe the longer-term fundamentals for copper remain compelling as
grade decline, rising costs and a scarcity of high-quality future development opportunities are likely to constrain
supply.
Demand growth, supply disruptions and geopolitical tension have continued to support crude oil prices. We
expect prices to remain supported by an increase in demand from non-OECD countries, which has recently
outstripped demand from OECD countries.
United States natural gas prices benefited from a cold winter which reduced inventory levels significantly below
the five-year average. In the longer term, demand is expected to benefit from increasing industrial use, growth in
gas fired power generation and the commencement of LNG exports. Conversely, high inventory levels at Asian
utilities, mild summer temperatures and the commissioning of additional supply have led to a decline in Asia-
Pacific LNG prices from their February peak.
The nickel price rose sharply during the period as the Indonesian ore export ban took effect in the March 2014
quarter. Demand growth remains robust given rising stainless steel production in China, Europe and the United
States.
While aluminium demand growth has been strong, new supply continues to offset the curtailment of high-cost
capacity. However, we expect the premia currently being realised in certain regions to remain at elevated levels
as warehouse bottlenecks are likely to take some time to be resolved.
In summary, a balanced global economic outlook should provide support for our markets, albeit with more
moderate rates of demand growth. In the longer term, wealth creation and urbanisation will remain the primary
drivers of commodities demand, although the transition to consumption-led growth in emerging economies should
provide particular support for industrial metals, energy and fertilisers.
Projects
BHP Billiton’s development capability was illustrated by the early completion of the WAIO Jimblebar Mine
Expansion and Queensland Coal Caval Ridge projects in the 2014 financial year. A further four projects were
successfully completed, namely: Macedon; North West Shelf North Rankin B Gas Compression; Samarco Fourth
Pellet Plant; and WAIO Port Blending and Rail Yard Facilities. The Newcastle Third Port Stage 3 project achieved
mechanical completion while the Cerrejón P40 project delivered first coal. The port expansion associated with the
Cerrejón P40 project is currently being commissioned, although operational issues are expected to constrain
capacity at approximately 35 Mtpa (100 per cent basis) in the medium term.
At the end of the 2014 financial year, BHP Billiton had eight major projects under development with a combined
budget of US$14.1 billion. During the period the Group approved: an investment of US$3.4 billion for the
construction of a desalination facility designed to deliver sustainable water supply to Escondida over the long
term; a US$2.6 billion investment to finish the excavation and lining of the Jansen Potash project production and
service shafts, and to continue the installation of essential surface infrastructure and utilities; and a US$212
million increase to the budget of the Escondida Oxide Leach Area project (OLAP) to US$933 million. While OLAP
is now scheduled for completion in the second half of the 2014 calendar year we expect no impact to production.
BHP Billiton’s share of capital and exploration expenditure(4) declined by 32 per cent during the 2014 financial
year to US$15.2 billion. Our rate of investment is expected to decline below our investment ceiling in the 2015
financial year with planned capital and exploration expenditure(4) of approximately US$14.8 billion.
Year ended Year ended
30 June 30 June
2014 2013
US$M US$M
Purchases of property, plant and equipment 15,993 22,243
Exploration expenditure 1,010 1,351
Capital and exploration expenditure (cash basis) 17,003 23,594
Add: equity accounted investments 871 1,493
Less: capitalised deferred stripping(i) (1,421) (1,650)
Less: non-controlling interests (1,272) (1,146)
Capital and exploration expenditure (BHP Billiton share)(ii) 15,181 22,291
(i) Includes US$243 million of capitalised deferred stripping attributable to non-controlling interests (June 2013 financial
year: US$292 million).
(ii) Represents the share of capital and exploration expenditure attributable to BHP Billiton shareholders on a cash basis.
Includes BHP Billiton proportionate share of equity accounted investments; excludes capitalised deferred stripping and
non-controlling interests.
Projects completed or delivered first production during the 2014 financial year
Business Project Capacity (i) Capital Date of initial
expenditure production
US$M(i)
Actual(ii) Budget Actual Target
Petroleum Macedon (Australia) 200 MMcf/d of gas. 1,200 1,050 Q3 CY13 CY13
71.43% (operator)
North West Shelf 2,500 MMcf/d of gas. 721 850 Q4 CY13 CY13
North Rankin B Gas
Compression
(Australia)
16.67% (non-operator)
Iron ore Samarco Fourth Pellet Increases Samarco iron ore pellet 1,576 1,750 Q1 CY14 H1CY14
Plant (Brazil) production capacity by 8.3 Mtpa to 30.5 Mtpa.
50%
WAIO Jimblebar Mine Increases mining and processing capacity to 3,380 3,640(iii) Q3 CY13 Q4 CY13(iv)
Expansion (Australia) 35 Mtpa with incremental debottlenecking (iv)
85% opportunities to 55 Mtpa.
WAIO Port Blending and Optimises resource and enhances efficiency 916 1,000(iii) Q4 CY13 H2 CY14
Rail Yard Facilities across the WAIO supply chain. (iv)
(Australia)
85%
Coal Caval Ridge Greenfield mine development to produce an 1,706 1,870(iii) Q2 CY14 CY14
(Australia) initial 5.5 Mtpa of export metallurgical coal.
50%
Newcastle Third Port Increases total coal terminal capacity from 367 367 Q3 CY13 CY14
Project Stage 3 53 Mtpa to 66 Mtpa.
(Australia)
35.5%
Cerrejón P40 Project Increases saleable thermal coal production by 437 437 Q4 CY13 CY13
(Colombia) 8 Mtpa to approximately 40 Mtpa.
33.3%
10,303 10,964
Projects in execution at the end of the 2014 financial year
Business Project Capacity(i) Capital Date of initial
expenditure production
US$M(i)
Budget Target
Petroleum North West Shelf Greater To maintain LNG plant throughput from the 400 CY16
Western Flank-A North West Shelf operations.
(Australia)
16.67% (non-operator)
Bass Strait Longford Gas Designed to process approximately 520 CY16
Conditioning 400 MMcf/d of high CO2 gas.
Plant (Australia)
50% (non-operator)
Copper Escondida Oxide Leach New dynamic leaching pad and mineral 933(iv) H2 CY14(iv)
Area Project (Chile) handling system. Maintains oxide leaching
57.5% capacity.
Escondida Organic New concentrator with 152 ktpd capacity. 3,838 H1 CY15
Growth Project 1 (Chile)
57.5%
Escondida Water Supply New desalination facility to ensure 3,430 CY17
(Chile) continued water supply to Escondida.
57.5%
Coal Hay Point Stage Three Increases port capacity from 44 Mtpa 1,505(iii)(iv) CY15(iv)
Expansion (Australia) to 55 Mtpa and reduces storm
50% vulnerability.
Appin Area 9 (Australia) Maintains Illawarra Coal’s production 845 CY16
100% capacity with a replacement mining domain
and capacity to produce 3.5 Mtpa of
metallurgical coal.
11,471
Other projects in progress at the end of the 2014 financial year
Business Project Scope Capital
Expenditure
(US$M)(i)
Budget
Potash Jansen Potash (Canada) Investment to finish the excavation and lining of 2,600
100% the 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 equity accounted investments and other operations are
reported at our equity share.
(ii) Number subject to finalisation.
(iii) Excludes announced pre-commitment funding.
(iv) As per revised budget and schedule.
Income statement
To provide additional clarity into the underlying performance of our operations we present Underlying EBIT, which
is a measure used internally. Exceptional items are described on page 12 and the difference between Underlying
EBIT and Profit from operations is set out in the following table:
Year ended 30 June 2014 2013
US$M US$M
Underlying EBIT 22,861 22,930
Exceptional items (before taxation) 551 (1,928)
Profit from operations (EBIT) 23,412 21,002
Underlying EBIT
The following table and commentary describes the approximate impact of the principal factors that affected
Underlying EBIT for the 2014 financial year compared with the 2013 financial year:
US$M
Underlying EBIT for the year ended 30 June 2013 22,930
Change in volumes:
Productivity 962
Growth 1,929
2,891
Net price impact:
Change in sales prices (3,396)
Price-linked costs (80)
(3,476)
Change in controllable cash costs:
Operating cash costs 1,524
Exploration and business development 398
1,922
Change in other costs:
Exchange rates 1,760
Inflation (805)
Fuel and energy (46)
Non-cash (2,091)
(1,182)
Asset Sales 53
Ceased and sold operations (492)
Other items 215
Underlying EBIT for the year ended 30 June 2014 22,861
The following table reconciles principal factors shown above with the Group’s productivity gains:
2014
US$M
Change in controllable cash costs 1,922
Changes in volumes (productivity) 962
Productivity gains (EBIT) 2,884
Change in capitalised exploration 10
Total productivity gains 2,894
Volumes
Productivity-led volume efficiencies and the ramp-up of major projects underpinned a nine per cent increase in
Group production(8) in the 2014 financial year and an additional US$2.9 billion in Underlying EBIT. WAIO was
the major contributor as the ramp-up of the Jimblebar mining hub and a series of productivity initiatives raised the
capacity of our integrated supply chain and supported a US$1.8 billion increase in Underlying EBIT. Despite the
impact of natural field decline, stronger volumes in our Petroleum business generated an additional US$994
million of Underlying EBIT, reflecting 73 per cent growth in Onshore US liquids volumes and a near doubling of
production at Atlantis.
We expect to maintain strong momentum and remain on track to generate Group production(8) growth of 16 per
cent over the two years to the end of the 2015 financial year.
Prices
Lower average prices reduced Underlying EBIT by US$3.4 billion in the 2014 financial year.
In metallurgical coal, an increase in seaborne supply and the resilience of higher cost, uneconomic capacity led
to a 20 per cent and 14 per cent decline in the average realised price of hard coking coal and weak coking coal,
respectively. The average price received for thermal coal also declined by 14 per cent during the period. In total,
lower average realised prices in our Coal business reduced Underlying EBIT by US$1.5 billion.
A five per cent decline in the average realised price of copper reflected the near-term rebalancing of the market
while the acceleration of low-cost, seaborne iron ore supply growth, predominantly from Australia’s Pilbara
region, weighed on prices in the June 2014 half year. In total, lower average realised prices for copper and iron
ore reduced Underlying EBIT by US$1.4 billion.
Nickel and aluminium prices rallied towards the end of the 2014 financial year but remained lower on average for
the period, reducing Underlying EBIT by a further US$258 million.
The value of diversification was again evident as higher average realised prices for our petroleum products
increased Underlying EBIT by US$219 million. In this context, the average price achieved for our natural gas
sales book, covering domestic and international markets, increased by 16 per cent.
Price-linked costs decreased Underlying EBIT by US$80 million during the period, primarily reflecting higher
royalty charges in our Petroleum and Iron Ore businesses.
Controllable cash costs
A broad-based improvement in productivity underpinned a significant US$1.9 billion reduction in controllable cash
costs(3) during the period.
Operating cash costs
The Group’s commitment to further improve the competitive position of its assets delivered tangible results in the
2014 financial year as operating cash costs declined by US$1.5 billion. A general increase in labour and
contractor productivity had the greatest impact, increasing Underlying EBIT by US$1.3 billion.
An improvement in equipment productivity increased Underlying EBIT by a further US$268 million as contract
stripping activities were further optimised at Queensland Coal. A reduction in consumable costs in our Aluminium,
Manganese and Nickel business more than accounted for a US$33 million decrease in Group supply costs.
Exploration and business development
The Group’s exploration expenditure declined by 25 per cent in the 2014 financial year to US$1.0 billion as we
sharpened our focus on greenfield copper porphyry targets in Chile and Peru, and high-impact liquids
opportunities in the Gulf of Mexico, Western Australia and Trinidad and Tobago. The associated reduction in the
Group’s exploration expense increased Underlying EBIT by US$331 million while a further decline in business
development expenditure increased Underlying EBIT by US$67 million.
Other Costs
Exchange rates
A stronger US dollar increased Underlying EBIT by US$1.8 billion and included the restatement of monetary
items in the balance sheet which reduced Underlying EBIT by US$352 million.
The following exchange rates have been applied:
Average Average
Year ended Year ended As at As at As at
30 June 30 June 30 June 30 June 30 June
2014 2013 2014 2013 2012
Australian dollar(i) 0.92 1.03 0.94 0.92 1.00
Chilean peso 532 479 551 504 510
Colombian peso 1,935 1,814 1,881 1,923 1,807
Brazilian real 2.29 2.04 2.20 2.18 2.08
South African rand 10.39 8.84 10.60 10.00 8.41
(i) Displayed as US$ to A$1 based on common convention.
Inflation
Inflation had an unfavourable impact on all businesses and reduced Underlying EBIT by US$805 million during
the 2014 financial year. This was most notable in Australia, Chile and South Africa, which accounted for over
85 per cent of the total variance.
Non-cash
An increase in non-cash charges reduced Underlying EBIT by US$2.1 billion during the period.
A US$631 million increase in the depreciation and amortisation charge at Onshore US reflected the ramp-up of
liquids production and the progressive development of our Permian acreage. We continue to expect the
depreciation rate in the Permian to normalise at a lower level as reserves are booked and the production rate
grows towards 100 Mboe per day over the medium term. The completion and progressive ramp-up of several
major projects in our Iron Ore and Coal businesses resulted in an US$871 million increase in the depreciation
and amortisation expense during the period.
Depreciation and amortisation expense included the following impairment charges: a US$292 million charge at
Energy Coal South Africa; a US$184 million charge related to minor Gulf of Mexico assets; and a US$68 million
charge associated with our decision to allow the exclusivity agreement for Terminal 5 at the Port of Vancouver
(US) to lapse.
A US$300 million charge related to the revision of mine site rehabilitation provisions for the Group’s North
American closed mines and a lower capitalisation rate for deferred stripping at Escondida and Pampa Norte also
contributed to the increase in non-cash charges.
Asset sales
The divestment of Liverpool Bay more than accounted for the US$53 million increase in Underlying EBIT related
to asset sales.
Ceased and sold operations
Underlying EBIT from ceased and sold operations decreased by US$492 million in the 2014 financial year and
largely reflected: a US$143 million adjustment to the Browse divestment proceeds; the closure of the Nickel West
Leinster Perseverance underground mine in November 2013; and the cessation of aluminium smelting activities
at Bayside in June 2014.
Other items
Other items increased Underlying EBIT by US$215 million and largely reflected an increase in margins at our
equity accounted investments and an US$84 million profit related to the sale of the Energy Coal South Africa
Optimum Coal Purchase agreement. A US$112 million UK pension plan expense in our Petroleum business is
also reported in this category.
Net finance costs
Net finance costs of US$1.2 billion were largely unchanged from prior period.
Taxation expense
The Group’s adjusted effective tax rate, which excludes the influence of exchange rate movements,
remeasurement of deferred tax assets associated with the Minerals Resource Rent Tax (MRRT) and exceptional
items, was 32.5 per cent (30 June 2013: 34.2 per cent). This adjusted effective tax rate is expected to remain in
the range of 30 per cent to 34 per cent for the 2015 financial year.
Government imposed royalty arrangements calculated by reference to profits are reported as royalty-related
taxation. The MRRT reduced taxation expense by US$238 million in the 2014 financial year (30 June
2013: increase of US$321 million) as royalty-related credits in the Coal business more than offset Iron Ore MRRT
expense for the period. This included the remeasurement of deferred tax assets associated with the MRRT which
decreased taxation expense by US$170 million in the period (30 June 2013: increase of US$207 million).
Total taxation expense, including royalty-related taxation, exceptional items and exchange rate movements, was
US$7.0 billion, representing a statutory effective tax rate of 31.5 per cent (30 June 2013: 35.0 per cent).
Year ended 30 June 2014 2013
Profit Income tax Profit Income tax
before tax expense before tax expense
US$M US$M % US$M US$M %
Statutory effective tax rate 22,236 (7,012) 31.5% 19,726 (6,906) 35.0%
Less:
Exchange rate movements - (24) - 245
Remeasurement of deferred tax assets
associated with the MRRT - (170) - 207
Exceptional items (551) 166 1,928 (943)
Adjusted effective tax rate 21,685 (7,040) 32.5% 21,654 (7,397) 34.2%
Other royalty and excise arrangements which are not profit based are recognised as operating costs within Profit
before taxation. These amounted to US$2.8 billion during the period (30 June 2013: US$2.6 billion).
Exceptional items
Year ended 30 June 2014 Gross Tax Net
US$M US$M US$M
Sale of Pinto Valley 551 (166) 385
551 (166) 385
On 11 October 2013, BHP Billiton completed the sale of its Pinto Valley mining operation for a cash consideration
of US$653 million, after working capital adjustments. A gain on sale of US$385 million (after tax expense) was
recognised in the 2014 financial year.
Cash flows
Net operating cash flows after interest and tax increased by 26 per cent to US$25.4 billion in the 2014 financial
year. A US$2.6 billion increase in cash generated from operations (after changes in working capital balances)
and a US$2.1 billion decrease in net taxes paid were the major contributors to the strong increase.
Net investing cash outflows decreased by US$2.9 billion to US$15.8 billion during the period. This reflected a
US$6.6 billion reduction in capital and exploration expenditure partially offset by a decline in proceeds from asset
sales of US$2.9 billion. Expenditure on major growth projects totalled US$13.1 billion, including US$5.6 billion on
petroleum projects and US$7.5 billion on minerals projects. Sustaining capital expenditure and other items
totalled US$2.9 billion. Exploration expenditure was US$1.0 billion, including US$716 million classified within net
operating cash flows.
Net financing cash flows included the proceeds from interest bearing liabilities of US$6.3 billion and contributions
from non-controlling interests of US$1.4 billion. Proceeds from interest bearing liabilities included the issuance of
a four tranche Global Bond of US$5.0 billion. These inflows were more than offset by debt repayments of
US$7.2 billion and dividend payments of US$6.4 billion.
Net debt finished the period at US$25.8 billion, a decrease of US$1.7 billion compared to the net debt position at
30 June 2013.
Dividend
BHP Billiton has a progressive dividend policy. The aim of this policy is to steadily increase or at least maintain
our base dividend in US dollars terms at each half-yearly payment. Our Board today determined to pay a final
dividend of 62 US cents per share. As a result, our total dividend for the 2014 financial year increases by four per
cent to 121 US cents per share. We will seek to steadily increase or at least maintain the dividend per share in
US dollar terms at each half-yearly payment following the demerger, implying a higher payout ratio.
The dividend to be paid by BHP Billiton Limited will be fully franked for Australian taxation purposes. Dividends
for the BHP Billiton Group are determined in US dollars. However, BHP Billiton Limited dividends are mainly paid
in Australian dollars, and BHP Billiton Plc dividends are mainly paid in pounds sterling and South African rand to
shareholders on the UK section and the South African section of the register, respectively. Currency conversions
will be based on the foreign currency exchange rates on the Record Date, except for the conversion into South
African rand, which will take place on the last day to trade (cum dividend) on JSE Limited, being 29 August 2014.
Please note that all currency conversion elections must be registered by the Record Date, being 5 September
2014. Any currency conversion elections made after this date will not apply to this dividend.
The timetable in respect of this dividend will be:
Last day to trade cum dividend on JSE Limited (JSE) and currency conversion into rand 29 August 2014
Ex-dividend Date JSE 1 September 2014
Ex-dividend Date Australian Securities Exchange (ASX), London Stock Exchange (LSE)
and New York Stock Exchange (NYSE) 3 September 2014
Record Date (including currency conversion and currency election dates, except for 5 September 2014
rand)
Payment date 23 September 2014
American Depositary Shares (ADSs) each represent two fully paid ordinary shares and receive dividends
accordingly.
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 1 September and 5 September 2014
(inclusive), nor will transfers between the UK register and the South African register be permitted between the
dates of 29 August and 5 September 2014 (inclusive).
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 2014 financial year, the Group issued a four tranche Global Bond comprising US$500 million Senior
Floating Rate Notes due 2016 paying interest at 3 month US Dollar LIBOR plus 25 basis points, US$500 million
2.050 per cent Senior Notes due 2018, US$1.5 billion 3.850 per cent Senior Notes due 2023, and US$2.5 billion
5.000 per cent Senior Notes due 2043.
In February 2014, the Group redeemed all outstanding Petrohawk Energy Corporation 10.5 per cent Senior
Notes due August 2014 and 7.875 per cent Senior Notes due June 2015 at the applicable call prices. The
aggregate principal value of the notes redeemed was approximately US$1.4 billion.
The Group has a US$6.0 billion commercial paper program backed by a US$6.0 billion revolving credit facility.
During the period, the Group’s revolving credit facilities, which consisted of US$1.0 billion expiring in December
2014 and US$5.0 billion expiring in December 2015, were replaced by a US$6.0 billion revolving credit facility.
The new facility has a five year maturity with two one-year extension options.
The Group’s balance sheet continued to strengthen during the 2014 financial year, consistent with our
commitment to maintain a solid A credit rating. At the end of the period, the Group’s cash and cash equivalents
on hand were US$8.8 billion.
Subsequent to the period end, the Group redeemed all outstanding Petrohawk Energy Corporation 7.25 per
cent Senior Notes due August 2018 and 6.25 per cent Senior Notes due June 2019 at the applicable call prices.
The aggregate principal value of the notes redeemed was approximately US$1.8 billion.
Corporate governance
On 15 April 2014, we announced the appointment of Mr Malcolm Brinded as a Non-executive Director, and a
member of the Sustainability Committee, effective
from that date. During the year, Carolyn Hewson was appointed to the Remuneration Committee and remains a
member of the Risk and Audit Committee. The Remuneration Committee is comprised of Sir John Buchanan,
Carlos Cordeiro, Pat Davies, Carolyn Hewson and John Schubert.
Business Summary(i)
The following table provides a summary of the performance of the businesses for the 2014 financial year and the
corresponding period.
Year ended Profit from Net
30 June 2014 Underlying Exceptional operations operating Capital Exploration Exploration
US$ million Revenue(ii) EBIT(iii) items (EBIT) assets(iv) expenditure(v) gross(vi) to profit(vii)
Petroleum and Potash 14,833 5,287 - 5,287 39,514 6,423 647 544
Copper 13,868 5,080 551 5,631 22,231 3,757 116 116
Iron Ore 21,356 12,102 - 12,102 23,390 2,949 169 56
Coal 9,115 386 - 386 14,300 2,345 34 34
Aluminium, Manganese
and Nickel 8,411 307 - 307 9,322 498 44 38
Group and unallocated
items (viii) 103 (301) - (301) 640 21 - -
Inter-segment adjustment (480) - - - - - - -
BHP Billiton Group 67,206 22,861 551 23,412 109,397 15,993 1,010 788
Year ended
30 June 2013 Profit from Net
(Republished) Underlying Exceptional operations operating Capital Exploration Exploration
US$ million Revenue(ii) EBIT(iii) items (EBIT) assets(iv) expenditure(v) gross(vi) to profit(vii)
Petroleum and Potash 13,224 5,636 1,273 6,909 37,525 7,675 764 709
Copper 14,537 5,639 355 5,994 20,074 3,930 274 274
Iron Ore 18,593 11,109 (827) 10,282 22,126 5,979 217 74
Coal 9,895 595 (79) 516 13,225 3,626 39 39
Aluminium,
Manganese
and Nickel 9,278 158 (3,923) (3,765) 8,809 893 57 53
Group and
unallocated items (viii) 501 (207) 1,273 1,066 328 140 - -
Inter-segment
adjustment (75) - - - - - - -
BHP Billiton Group 65,953 22,930 (1,928) 21,002 102,087 22,243 1,351 1,149
(i) Group and business level information is reported on a statutory basis which, in relation to Underlying EBIT, includes net
finance costs and taxation associated with 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$2,979 million and Underlying EBIT of US$44 million (2013: US$2,886 million and US$127
million).
(iii) Underlying EBIT is defined as earnings before net finance costs, taxation and any exceptional items. Underlying EBIT is
reported net of net finance costs of US$90 million and taxation of US$438 million associated with equity accounted
investments (2013: net finance costs of US$24 million and taxation of US$616 million). Underlying EBITDA, as reported
within each business, is Underlying EBIT before depreciation, impairments and amortisation (D&A).
(iv) 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 associate.
(v) Capital expenditure is presented on a cash basis and excludes capitalised interest and capitalised exploration. Capital
expenditure in aggregate comprises US$13,130 million growth and US$2,863 million other (2013: US$18,678 million
growth and US$3,565 million other). Comparative period capital expenditure was previously reported on an accruals
basis and has been restated on a cash basis.
(vi) Includes US$294 million capitalised exploration (2013: US$304 million).
(vii) Includes US$72 million exploration expenditure previously capitalised, written off as impaired (included in depreciation
and amortisation) (2013: US$102 million).
(viii)Includes the Group's diamonds business (divested effective 10 April 2013), interest in titanium minerals (divested
effective 3 September 2012), non-Potash corporate costs incurred by the former Diamonds and Specialty Products
business, consolidation adjustments, unallocated items and external sales of freight and fuel via the Group's transport
and logistics operations.
Petroleum and Potash
Total petroleum production increased by four per cent in the 2014 financial year to 246 MMboe. A 16 MMboe
increase in liquids production was underpinned by a 73 per cent increase in Onshore US liquids volumes and a
near doubling of production at Atlantis. Natural gas volumes declined by four per cent as the delivery of first gas
from Macedon partially offset lower demand at Bass Strait and natural field decline at Haynesville. Petroleum
production(9) is forecast to increase by five per cent in the 2015 financial year to 255 MMboe with another
16 MMboe increase in total liquids production projected. Conventional volumes for the 2015 financial year are
forecast to remain broadly unchanged, consistent with prior guidance.
Total petroleum production (MMboe) Total
2014 financial year 246
Less: divested assets (3)
Adjusted 2014 financial year 243
Forecast change in liquids volumes 16
Forecast change in gas volumes (4)
2015 financial year 255
The average realised price of natural gas across our portfolio increased by 16 per cent to US$4.35 per Mscf and
was the major contributor to the US$113 million price-related increase in Underlying EBIT during the period, net
of price-linked costs. This included a 25 per cent increase in the average realised price of US natural gas to
US$4.10 per Mscf. These gains were partially offset by a four per cent decline in the average realised price of oil
to US$102 per bbl, a one per cent decline in the average realised price of LNG to US$14.67 per Mscf and a
seven per cent decline in the average realised price of natural gas liquids (NGL) to US$42.28 per boe.
Underlying EBIT for Petroleum decreased by US$115 million to US$5.9 billion in the 2014 financial year.
Volumes contributed an additional US$994 million to Underlying EBIT, although this was partially offset by an
increase in depreciation and amortisation expense at Onshore US that reflected the ramp-up of liquids production
and the progressive development of our Permian acreage. We continue to expect the depreciation rate in the
Permian to normalise at a lower level as reserves are booked and the production rate grows towards 100 Mboe
per day over the medium term. In this regard, our position in our focus area of the Permian increased by 25 per
cent in the period to 74 thousand net acres.
Additional charges were also recognised during the period, including: a US$184 million impairment of minor Gulf
of Mexico assets; a US$143 million adjustment to the Browse divestment proceeds; and a US$112 million UK
pension plan expense. The Group also incurred a charge of US$135 million for underutilised gas pipeline
capacity, primarily in the Haynesville. As we continue to prioritise the development of our liquids-rich acreage we
expect a further US$170 million of underutilised gas pipeline capacity charges in the 2015 financial year, before
they decline substantially in the 2016 financial year.
Onshore US Underlying EBITDA increased by more than 60 per cent in the June 2014 half year to US$1.4 billion.
As a result, Onshore US was profitable during this period, generating Underlying EBIT of US$284 million on an
annualised basis. This included costs associated with early stage exploration in the Pearsall and the
aforementioned underutilised gas pipeline capacity charges. A six per cent reduction in unit costs contributed to
this strong improvement in financial performance. With a 17 MMboe increase in liquids production and further
improvements in productivity anticipated, we remain confident that Onshore US will be strongly EBIT positive in
the 2015 financial year.
In the 2014 financial year, approximately 75 per cent of Onshore US drilling and development expenditure of
US$4.2 billion was invested in the Eagle Ford, with the majority focused on our Black Hawk acreage. The
repetitive, manufacturing-like nature of shale development is ideally suited to our productivity agenda and we are
delivering strong results. Drilling costs in the Black Hawk declined by 16 per cent to US$4.2 million per well
during the period while spud to sales timing improved by 21 per cent.
Of the 24 operated drilling rigs in action at the end of the period (30 June 2013: 40), 17 were in the Eagle Ford
(30 June 2013: 31), four were in the Permian (30 June 2013: four), three were in the Haynesville (30 June
2013: four), while no rigs were in the Fayetteville (30 June 2013: one).
A total of 138 net wells were put online in our prolific Black Hawk acreage during the period (2013 financial
year: 66 net wells) with an average 30-day initial production rate of 1,140 boe per day. An average one-year
cumulative production rate per well of 208 Mboe for the wells put online in the 2013 financial year reflected
advances in completions optimisation and the benefit of restricting initial flow rates. At the end of the period we
had 284 net producing wells in the Black Hawk with an average rate of 82.4 Mboe per day achieved in the June
2014 quarter (43.0 Mboe per day in the June 2013 quarter).
Onshore US Liquids focused areas Gas focused areas
2014 financial year (Eagle Ford and (Haynesville and
(2013 financial year) Permian) Fayetteville) Total
Capital expenditure US$ billion 3.6 (3.8) 0.6 (0.9) 4.2 (4.7)
Production MMboe 51.9 (33.4) 56.2 (65.8) 108.1 (99.2)
Production mix Natural gas 36% (42%) 100% (100%) 69% (80%)
Natural gas liquids 22% (23%) - (-) 11% (8%)
Crude and condensate 42% (35%) - (-) 20% (12%)
Petroleum capital expenditure of approximately US$5.6 billion is planned in the 2015 financial year. In our
Onshore US business we will continue to prioritise investment in the liquids-rich Eagle Ford and Permian with up
to 120 net wells expected to be put online in the Black Hawk. In our Conventional business, we will remain
focused on high-return infill drilling opportunities in the Gulf of Mexico and life extension projects at Bass Strait
and North West Shelf.
Petroleum exploration expenditure for 2014 financial year was US$600 million, of which US$369 million was
expensed. During the period, BHP Billiton signed a production sharing contract for Block 23b (60 per cent interest
and operator) and farmed into Blocks 23a and 14 (70 per cent interest and operator) in Trinidad and Tobago. A
US$750 million exploration program, largely focused on the Gulf of Mexico, Western Australia and the collection
of seismic data in Trinidad and Tobago is planned for the 2015 financial year.
During the period, BHP Billiton completed the divestment of its 46.1 per cent interest in Liverpool Bay and its
South Midland acreage in the Permian basin, Onshore US. Combined proceeds of US$182 million were realised
(before customary adjustments) and a gain on sale of US$116 million was recognised in Underlying EBIT.
Potash recorded an Underlying EBIT loss of US$583 million. This included: a US$68 million impairment
associated with our decision to allow the exclusivity agreement for Terminal 5 at the Port of Vancouver (US) to
lapse; and a US$300 million charge related to the revision of mine site rehabilitation provisions for the Group’s
North American closed mines, which are managed by our Potash business. These charges were partially offset
by a US$42 million reduction in exploration expense.
On 20 August 2013, BHP Billiton announced an additional investment of US$2.6 billion to finish the excavation
and lining of the Jansen Potash project production and service shafts, and to continue the installation of essential
surface infrastructure and utilities. The overall project was 30 per cent complete at the end of the period with
significant progress made on surface infrastructure and shaft excavation continuing.
Financial information for the Petroleum and Potash business for the 2014 and 2013 financial years is presented
below.
Year ended Net
30 June 2014 (i) Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue(ii) EBITDA D&A EBIT assets expenditure(iii) gross(iv) to profit(v)
Bass Strait 1,885 1,555 132 1,423 2,864 259
North West Shelf(vi) 2,432 1,599 175 1,424 1,691 193
Atlantis 1,535 1,407 335 1,072 2,272 409
Shenzi 1,430 1,281 243 1,038 1,598 306
Mad Dog 217 171 16 155 461 83
Onshore US 4,264 2,270 2,426 (156) 26,945 4,226
Algeria 465 396 30 366 104 19
UK(vii) 155 70 52 18 (38) 15
Exploration - (369) 113 (482) 464 -
Other(viii) (ix) 2,027 1,744 735 1,009 1,907 369
Total Petroleum 14,410 10,124 4,257 5,867 38,268 5,879 600 497
Potash - (211) 74 (285) 2,255 544 47 47
Other(x) - (298) - (298) (1,009) - - -
Total Petroleum and
Potash from Group
production 14,410 9,615 4,331 5,284 39,514 6,423 647 544
Third party products 437 3 - 3 - -
Total Petroleum and
Potash 14,847 9,618 4,331 5,287 39,514 6,423 647 544
Statutory adjustments(xi) (14) (3) (3) - - - - -
Total Petroleum and
Potash statutory result 14,833 9,615 4,328 5,287 39,514 6,423 647 544
Year ended
30 June 2013 Net
(Republished) (i) Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue(ii) EBITDA D&A EBIT assets expenditure (iii) gross(iv) to profit (v)
Bass Strait 1,921 1,564 119 1,445 2,834 526
North West Shelf 2,578 1,913 234 1,679 1,880 221
Atlantis 853 710 147 563 2,166 419
Shenzi 1,614 1,519 283 1,236 1,524 289
Mad Dog 276 233 98 135 420 89
Onshore US 2,987 1,508 1,795 (287) 25,019 4,699
Algeria 533 460 18 442 90 22
UK 244 95 46 49 45 8
Exploration - (522) 230 (752) 529 -
Other(viii) (ix) 2,032 1,746 282 1,464 1,973 794
Total Petroleum 13,038 9,226 3,252 5,974 36,480 7,067 675 620
Potash - (309) 25 (334) 1,758 608 89 89
Other(x) 18 (15) - (15) (713) - - -
Total Petroleum and
Potash from Group
production 13,056 8,902 3,277 5,625 37,525 7,675 764 709
Third party products 175 11 - 11 - -
Total Petroleum and
Potash 13,231 8,913 3,277 5,636 37,525 7,675 764 709
Statutory adjustments(xi) (7) (3) (3) - - - - -
Total Petroleum and
Potash statutory result 13,224 8,910 3,274 5,636 37,525 7,675 764 709
(i) Petroleum revenue from Group production includes: crude oil US$8,645 million (2013: US$7,604 million), natural gas
US$3,119 million (2013: US$2,842 million), LNG US$1,614 million (2013: US$1,686 million), NGL US$916 million
(2013: US$823 million) and other US$102 million (2013: US$76 million).
(ii) Includes inter-segment revenue of US$262 million (2013: US$ nil).
(iii) Capital expenditure in aggregate comprises Petroleum US$5,600 million growth and US$279 million other (2013:
US$6,883 million growth and US$184 million other) and Potash US$533 million growth and US$11 million other (2013:
US$597 million growth and US$11 million other).
(iv) Includes US$231 million of Petroleum capitalised exploration (2013: US$153 million).
(v) Includes US$128 million of Petroleum exploration expenditure previously capitalised, written off as impaired (included in
depreciation and amortisation) (2013: US$98 million).
(vi) Includes an expense of US$143 million incurred in May 2014 related to the purchase price adjustment for the Browse
asset sale completed in the 2013 financial year.
(vii) Includes an expense of US$112 million incurred in November 2013 related to the closure of the UK pension plan. Also
includes a gain of US$120 million related to the sale of the Liverpool Bay asset in March 2014.
(viii) Includes Macedon, Pyrenees, Stybarrow, Neptune, Minerva, Angostura, Genesis, Pakistan, divisional activities,
business development 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).
(ix) Includes an unrealised gain of US$74 million related to Angostura embedded derivative (2013: US$84 million unrealised
loss).
(x) Includes closed mining and smelting operations in Canada and the United States.
(xi) Includes statutory adjustments for the Caesar oil pipeline and the Cleopatra gas pipeline to reconcile the proportionately
consolidated business total to the statutory result.
Copper
Total copper production increased by two per cent in the 2014 financial year to 1.7 Mt, as planned. Escondida
copper production increased by two per cent to 1.2 Mt as an improvement in mill throughput and concentrator
utilisation offset declining ore grades. Record mining rates at Olympic Dam underpinned an 11 per cent increase
in copper production to 184 kt while Pampa Norte copper production of 233 kt was unchanged from the prior
period. Antamina achieved record annual mill throughput and copper production in the 2014 financial year.
Total copper production(9) is forecast to increase by five per cent in the 2015 financial year to 1.8 Mt. With further
improvements in productivity anticipated, Escondida is on track to produce approximately 1.27 Mt of copper in the
period. Copper volumes at Pampa Norte and Olympic Dam are expected to remain at a similar level to the
2014 financial year while lower average copper grades are expected to lead to a reduction in copper production
at Antamina in the 2015 financial year, consistent with the mine plan.
Lower average realised prices reduced Underlying EBIT by US$947 million, net of price-linked costs. A five per
cent decline in the average realised price of copper to US$3.22 per pound was the major contributor. In contrast,
a stronger US dollar against the Chilean peso and Australian dollar increased Underlying EBIT by US$359
million.
Underlying EBIT for the 2014 financial year decreased by US$559 million to US$5.1 billion. Unit cash costs at our
operated copper assets declined by six per cent during the 2014 financial year despite the impact of a nine per
cent reduction in ore grades at Escondida. In this context, productivity-led cost efficiencies increased Underlying
EBIT by US$190 million and reflected insourcing initiatives and the broader optimisation of contractor activities
across the business. A reduction in exploration and business development expenditure increased Underlying
EBIT by a further US$217 million as the Group sharpened its focus on greenfield copper porphyry targets in Chile
and Peru. In contrast, an increase in non-cash charges reflected a lower capitalisation rate for deferred stripping
at Escondida and Pampa Norte, and a general increase in depreciation and amortisation, and reduced
Underlying EBIT by US$337 million during the period.
At 30 June 2014, the Group had 350 kt of outstanding copper sales that were revalued at a weighted average
price of US$3.19 per pound. The final price of these sales will be determined in the 2015 financial year. In
addition, 386 kt of copper sales from the 2013 financial year were subject to a finalisation adjustment in 2014.
These provisional pricing and finalisation adjustments increased Underlying EBIT by US$73 million in the 2014
financial year (2013 financial year: US$303 million decrease; December 2013 half year: US$196 million
increase).
During the period, we completed the sale of the Pinto Valley mining operation and the associated San Manuel
Arizona Railroad Company to Capstone Mining Corporation for US$653 million, after working capital adjustments.
A gain on sale of US$385 million (after tax) was recognised in the 2014 financial year and was reported as an
exceptional item.
In July 2013, we announced an investment of US$3.4 billion to construct a desalination facility which will deliver
sustainable water supply to Escondida over the long term. A US$212 million increase to the budget of the
Escondida Oxide Leach Area project to US$933 million was also approved during the period. The project is now
scheduled for completion in the second half of the 2014 calendar year. The commissioning of Organic Growth
Project 1, which remains on schedule to commence in the June 2015 quarter, will create 152 kt per day of
valuable copper concentrator capacity. The Escondida Oxide Leach Area project and Organic Growth Project 1
are expected to maintain Escondida’s copper production at an elevated level.
In July 2014, we lodged an application for assessment by the Australian and South Australian Governments to
construct and operate a demonstration plant on the existing mining lease at Olympic Dam. This process would
enable heap leaching trials to progress to the next phase as part of our efforts to identify an alternative, less
capital intensive process for extracting metals from ore mined underground. Should government and Board
approvals be granted, construction of the demonstration plant is expected to commence in the second half of the
2015 calendar year. A trial period of 36 months is envisaged, commencing in late 2016.
Financial information for the Copper business for the 2014 and 2013 financial years is presented below.
Year ended Net
30 June 2014 Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue EBITDA D&A EBIT assets expenditure(i) gross to profit
Escondida(ii) 8,085 4,754 760 3,994 11,779 3,186
Pampa Norte(iii) 1,796 785 429 356 2,575 336
Antamina(iv) 1,261 818 84 734 1,341 262
Cannington 1,079 459 47 412 234 60
Olympic Dam 1,777 299 265 34 6,320 167
Other(iv) (v) 101 (193) 7 (200) (18) 13
Total Copper from
Group production 14,099 6,922 1,592 5,330 22,231 4,024
Third party products 1,030 8 - 8 - -
Total Copper 15,129 6,930 1,592 5,338 22,231 4,024 118 118
Statutory adjustments (vi) (1,261) (344) (86) (258) - (267) (2) (2)
Total Copper
statutory result 13,868 6,586 1,506 5,080 22,231 3,757 116 116
Year ended
30 June 2013 Net
(Republished) Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue EBITDA D&A EBIT assets expenditure(i) gross to profit
Escondida(ii) 8,596 5,175 649 4,526 9,450 2,859
Pampa Norte(iii) 1,913 841 291 550 2,643 348
Antamina(iv) 1,295 901 80 821 1,311 326
Cannington 1,365 646 40 606 206 39
Olympic Dam 1,873 245 249 (4) 6,418 399
Other(iv) (v) 90 (554) 19 (573) 46 289
Total Copper from
Group production 15,132 7,254 1,328 5,926 20,074 4,260
Third party products 700 3 - 3 - -
Total Copper 15,832 7,257 1,328 5,929 20,074 4,260 277 277
Statutory adjustments (vi) (1,295) (372) (82) (290) - (330) (3) (3)
Total Copper
statutory result 14,537 6,885 1,246 5,639 20,074 3,930 274 274
(i) Capital expenditure in aggregate comprises US$2,629 million growth and US$1,128 million other (2013: US$2,167
million growth and US$1,763 million other).
(ii) Escondida is consolidated under IFRS 10 and reported on a 100 per cent basis.
(iii) Includes Spence and Cerro Colorado.
(iv) Antamina and Resolution are equity accounted investments and are reported on a proportionate consolidation basis
(with the exception of net operating assets).
(v) Predominantly comprises divisional activities, greenfield exploration, business development and ceased and sold
operations. Includes Pinto Valley and Resolution. Pinto Valley was sold effective 11 October 2013.
(vi) Includes statutory adjustments for Antamina and Resolution to reconcile the proportionately consolidated business total
to the statutory result. Statutory Underlying EBIT includes net finance costs of US$4 million and taxation of US$254
million (2013: net finance costs of US$ nil and taxation of US$290 million).
Iron Ore
Iron ore production increased by 20 per cent in the 2014 financial year to a record 204 Mt, exceeding initial full-
year guidance by more than eight per cent. WAIO production of 225 Mt (100 per cent basis) represents a
fourteenth consecutive annual record and was underpinned by the early commissioning of Jimblebar and our
productivity agenda, which raised the capacity of our integrated supply chain.
In the 2015 financial year WAIO production is expected to increase by a further 20 Mt to approximately 245 Mt
(100 per cent basis). We expect additional productivity gains to support another year of record performance
despite the planned tie-in of shiploaders 1 and 2 during the December 2014 half year. Total iron ore production is
forecast to increase by 11 per cent in the 2015 financial year to 225 Mt.
A low-cost option to expand Jimblebar to 55 Mtpa (100 per cent basis) and broader debottlenecking of our mines
and inner harbour infrastructure are expected to underpin further growth in WAIO supply-chain capacity to
290 Mtpa (100 per cent basis). The additional 65 Mtpa of capacity is likely to have a capital intensity below
US$50 per annual tonne with the improvement in productivity and economies of scale also expected to
significantly reduce unit costs.
A six per cent fall in the average realised price of iron ore to US$103 per wet metric tonne (FOB) reduced
Underlying EBIT by US$864 million, net of price-linked costs, although this was partially offset by a weaker
Australian dollar which increased Underlying EBIT by US$383 million. Iron ore sales, on average, were linked to
the index price for the month of shipment, with price differentials reflecting product quality.
Underlying EBIT for the 2014 financial year increased by US$993 million to US$12.1 billion. An 18 per cent
increase in WAIO sales volumes was the major contributor, adding US$1.8 billion to Underlying EBIT.
Conversely, the progressive ramp-up of several major projects resulted in a US$425 million increase in
depreciation and amortisation expense during the period. Having redirected the WAIO supply-chain bottleneck
away from the mines and back to the port, a 12 per cent reduction in unit costs to US$25.89 per tonne was
achieved in the June 2014 half year.
WAIO unit costs (US$ million) FY13 FY14 H1 FY14 H2 FY14
Revenue 18,452 21,013 10,849 10,164
Underlying EBITDA 11,668 12,988 6,801 6,187
Cash costs (gross) 6,784 8,025 4,048 3,977
Less: freight 856 1,274 625 648
Less: royalties 1,192 1,497 744 753
Cash costs (Net) 4,736 5,254 2,679 2,576
Sales (Mt, equity share) 160,955 190,843 91,327 99,516
Cash cost per tonne (US$) 29.42 27.53 29.33 25.89
A number of major project milestones were achieved during the period, further underscoring Iron Ore’s track
record in project delivery. For example, the Jimblebar Mine Expansion project delivered first production six
months ahead of schedule and the ramp-up to 35 Mtpa (100 per cent basis) is now expected before the end of
the 2014 calendar year. The WAIO Port Blending and Rail Yard Facilities project and fourth pellet plant at
Samarco were also completed during the period. The fourth pellet plant is expected to ramp-up to 30.5 Mtpa (100
per cent basis) before the end of the 2015 financial year.
On 29 July 2014, BHP Billiton and ArcelorMittal signed an agreement for the acquisition by ArcelorMittal of
BHP Billiton's 43.5 per cent stake in Euronimba Limited, which holds an effective 95 per cent interest in the
Mount Nimba iron ore project in Guinea. Completion of the transaction is subject to the receipt of regulatory
approval and other customary closing conditions.
Financial information for the Iron Ore business for the 2014 and 2013 financial years is presented below.
Year ended Net
30 June 2014 Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue(i) EBITDA D&A EBIT assets expenditure (ii) gross (iii) to profit(iv)
Western Australia
Iron Ore 21,013 12,988 1,429 11,559 22,278 2,947
Samarco(v) 1,634 846 56 790 1,072 424
Other(vi) - (54) - (54) 40 -
Total Iron Ore from
Group production 22,647 13,780 1,485 12,295 23,390 3,371
Third party products(vii) 343 (3) - (3) - -
Total Iron Ore 22,990 13,777 1,485 12,292 23,390 3,371 169 56
Statutory adjustments (viii) (1,634) (246) (56) (190) - (422) - -
Total Iron Ore
statutory result 21,356 13,531 1,429 12,102 23,390 2,949 169 56
Year ended Net
30 June 2013 Underlying Underlying operating Exploration Exploration
Revenue(i) EBITDA D&A EBIT assets Capital gross(iii) to profit(iv)
(Republished) Expenditure(ii)
US$ million
Western Australia
Iron Ore 18,452 11,668 1,004 10,664 21,074 5,979
Samarco(v) 1,622 811 61 750 1,037 772
Other(vi) - (84) - (84) 15 -
Total Iron Ore from
Group production 20,074 12,395 1,065 11,330 22,126 6,751
Third party products(vii) 141 31 - 31 - -
Total Iron Ore 20,215 12,426 1,065 11,361 22,126 6,751 217 74
Statutory adjustments (viii) (1,622) (313) (61) (252) - (772) - -
Total Iron Ore
statutory result 18,593 12,113 1,004 11,109 22,126 5,979 217 74
(i) Includes inter-segment revenue of US$213 million (2013: US$55 million).
(ii) Capital expenditure in aggregate comprises US$2,762 million growth and US$187 million other (2013: US$5,848 million
growth and US$131 million other).
(iii) Includes US$57 million capitalised exploration (2013: US$143 million).
(iv) Includes a reversal of US$56 million of exploration expenditure previously written off as impaired (included in
depreciation and amortisation) (2013: US$ nil).
(v) Samarco is an equity accounted investment and is reported on a proportionate consolidation basis (with the exception of
net operating assets).
(vi) Predominantly comprises divisional activities, business development and ceased operations.
(vii) Includes inter-segment and external sales of contracted gas purchases.
(viii)Includes statutory adjustments for Samarco to reconcile the proportionately consolidated business total to the statutory
result. Statutory Underlying EBIT includes net finance costs of US$87 million and taxation of US$103 million (2013: net
finance costs of US$25 million and taxation of US$227 million).
Coal
Metallurgical coal production increased by 20 per cent in the 2014 financial year to a record 45 Mt (BHP Billiton share).
Record production and sales volumes at Queensland Coal reflected strong performance across all operations. This included
first production from Caval Ridge, the successful ramp-up of Daunia and record production at Peak Downs, Saraji, South
Walker Creek and Poitrel. Illawarra Coal production declined by five per cent as an extended outage at the Dendrobium mine
impacted performance in the first half of the financial year.
Energy coal production of 73 Mt for the 2014 financial year was broadly unchanged from the prior period as planned.
Another year of robust performance was underpinned by a fifth consecutive annual production record at New South Wales
Energy Coal and record volumes at Cerrejón. Extended outages at both a local utility and the Richards Bay Coal Terminal
led to lower production at Energy Coal South Africa, while Navajo Coal production declined following the permanent closure
of three of the five power units at the Four Corners Power Plant.
Metallurgical coal production for the 2015 financial year is expected to increase by four per cent to approximately 47 Mt as
the ramp-up of Caval Ridge is completed. Energy coal production for the 2015 financial year is expected to remain broadly
unchanged at 73 Mt.
A stronger US dollar against both the Australian dollar and South African rand increased Underlying EBIT by US$543 million.
This was more than offset by a 20 per cent and 14 per cent reduction in the average price received for hard coking coal and
weak coking coal, respectively. The average price received for thermal coal also declined by 14 per cent during the period. In
total, lower average realised prices reduced Underlying EBIT by US$1.4 billion, net of price-linked costs.
Underlying EBIT for the 2014 financial year declined by US$209 million to US$386 million despite productivity-led volume
and cost efficiencies of US$1.3 billion being embedded during the period. A sustainable increase in truck and wash-plant
utilisation rates underpinned this improvement in productivity while a reduction in labour, contractor and maintenance costs
was also achieved. In this context, redundancies totalling US$40 million were recognised in the 2014 financial year while an
increase in non-cash charges reduced Underlying EBIT by a further US$497 million. The latter included a US$292 million
impairment charge at Energy Coal South Africa. An US$84 million gain on the sale of the Energy Coal South Africa Optimum
Coal Purchase agreement was also recognised during the period.
BHP Billiton completed the sale of the Navajo mine to the Navajo Transitional Energy Company (NTEC), effective 30
December 2013. As BHP Billiton will retain control of the mine until full consideration is received from NTEC, production and
financial results for the Navajo mine will continue to be reported by the Group.
The Caval Ridge project was completed ahead of schedule and under budget during the period with the ramp-up to 5.5 Mtpa
of premium hard coking coal expected by the end of the 2015 financial year. The Appin Area 9 and Hay Point Stage Three
Expansion (10) projects remain on schedule and budget.
Financial information for the Coal business for the 2014 and 2013 financial years in presented below.
Year ended Net
30 June 2014 Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue EBITDA D&A EBIT assets expenditure(i) gross to profit
Queensland Coal 4,666 949 514 435 9,115 1,790
Illawarra(ii) 886 131 170 (39) 1,384 309
Energy Coal South Africa(ii) 1,279 315 485 (170) 989 65
New Mexico 520 105 46 59 202 26
New South Wales
Energy Coal(ii) 1,350 324 150 174 1,392 170
Colombia(ii) 814 305 85 220 1,037 133
Other(iii) - (166) 2 (168) 162 34
Total Coal from
Group production 9,515 1,963 1,452 511 14,281 2,527
Third party products 456 18 - 18 19 -
Total Coal 9,971 1,981 1,452 529 14,300 2,527 34 34
Statutory adjustments (iv) (856) (264) (121) (143) - (182) - -
Total Coal
statutory result 9,115 1,717 1,331 386 14,300 2,345 34 34
Year ended
30 June 2013 Net
(Republished) Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue EBITDA D&A EBIT assets expenditure(i) gross to profit
Queensland Coal 4,452 627 376 251 7,988 2,771
Illawarra(ii) 1,287 311 148 163 1,238 357
Energy Coal South Africa(ii) 1,457 177 211 (34) 1,334 133
New Mexico 588 95 49 46 164 28
New South Wales
Energy Coal(ii) 1,526 314 120 194 1,372 366
Colombia(ii) 828 307 65 242 997 265
Other(iii) - (158) 2 (160) 111 85
Total Coal from
Group production 10,138 1,673 971 702 13,204 4,005
Third party products 585 44 - 44 21 -
Total Coal 10,723 1,717 971 746 13,225 4,005 42 42
Statutory adjustments (iv) (828) (237) (86) (151) - (379) (3) (3)
Total Coal
statutory result 9,895 1,480 885 595 13,225 3,626 39 39
(i) Capital expenditure in aggregate comprises US$1,563 million growth and US$782 million other (2013: US$2,898 million
growth and US$728 million other).
(ii) Cerrejon, Newcastle Coal Infrastructure Group, Port Kembla Coal Terminal and Richards Bay Coal Terminal are equity
accounted investments and are reported on a proportionate consolidation basis (with the exception of net operating
assets).
(iii) Predominantly comprises divisional activities and greenfield projects.
(iv) Includes statutory adjustments for Cerrejon, Newcastle Coal Infrastructure Group, Port Kembla Coal Terminal and
Richards Bay Coal Terminal to reconcile the proportionately consolidated business total to the statutory result. Statutory
Underlying EBIT includes net finance income of US$1 million and taxation of US$81 million (2013: net finance income of
US$1 million and taxation of US$99 million).
Aluminium, Manganese and Nickel
Alumina production increased by six per cent in the 2014 financial year to a record 5.2 Mt. The Efficiency and
Growth project at Worsley reached nameplate capacity during the year and annual production records were
achieved at both the Worsley and Alumar refineries. Aluminium production of 1.2 Mt was unchanged from the
2013 financial year with production records at both Hillside and Mozal offset by lower volumes at Alumar following
the phased suspension of 103 kt (BHP Billiton share) of annualised capacity.
Manganese ore production declined by three per cent in the 2014 financial year to 8.3 Mt as GEMCO was
affected by higher than usual rainfall during the wet season. Manganese alloy production increased by six per
cent from the 2013 financial year which was affected by the temporary suspension of operations at TEMCO.
Nickel production declined by seven per cent in the 2014 financial year to 143 kt. Production at Cerro Matoso was
affected by kiln and furnace outages, and lower nickel grades. Nickel West production declined by four per cent
following the closure of the Perseverance underground mine in November 2013. Saleable nickel production at
Nickel West is expected to decline by four per cent in the 2015 financial year to 95 kt with approximately
55 per cent to be sourced from third party feed. Ferro-nickel production at Cerro Matoso is expected to decline by
three per cent to 43 kt as a result of lower grades.
Notwithstanding a rebound in nickel and aluminium prices in the second half, lower average realised prices
reduced Underlying EBIT by US$409 million during the 2014 financial year, net of price-linked costs. More
specifically, lower average realised prices for aluminium (down six per cent to US$2,022 per tonne), manganese
ore (down four per cent to US$4.64 per dry metric tonne unit), manganese alloy (down six per cent to US$980
per tonne) and nickel (down seven per cent to US$14,925 per tonne) were only partially offset by an increase in
the average realised price of alumina (up two per cent to US$307 per tonne).
Underlying EBIT for the 2014 financial year increased by US$149 million to US$307 million. A reduction in
headcount and consumable costs, as well as equipment debottlenecking at most assets, contributed to the
US$335 million of productivity-led cost efficiencies embedded during the period. A stronger US dollar against
both the Australian dollar and South African rand increased Underlying EBIT by a further US$469 million. In
contrast, the cessation of aluminium smelting activities at Bayside and the closure of the Perseverance
underground mine at Nickel West reduced Underlying EBIT by US$341 million. Redundancies totalling US$40
million were incurred during the period.
In May 2014, the Group announced a review of the Nickel West business, comprising the Mt Keith, Cliffs and
Leinster mines, its concentrators, the Kalgoorlie smelter and the Kwinana refinery. The review is considering all
options for the long-term future of Nickel West, including the potential sale of all or part of the business.
In contemplation of the proposed demerger, BHP Billiton and Anglo American have agreed to make certain
changes to the agreement which governs their interests in the Manganese business. BHP Billiton manages and
owns 60 per cent of the Manganese business with Anglo American owning the remaining 40 per cent.
Subject to obtaining the required approvals for the agreement will result in BHP Billiton and Anglo American
agreeing to share joint control of the Manganese business. As a result, BHP Billiton will discontinue consolidation
of the Manganese business and account for its 60 per cent interest as an equity accounted joint venture. BHP
Billiton will therefore derecognise the existing carrying amounts of all assets, liabilities and the non-controlling
interest in the Manganese business attributed to Anglo American and initially record its retained 60 per cent
interest at fair value. The remeasurement at fair value will give rise to an estimated gain of approximately US$2
billion.
Financial information for the Coal business for the 2014 and 2013 financial years is presented below.
Year ended Net
30 June 2014 Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue EBITDA D&A EBIT assets expenditure(i) gross to profit
Alumina 1,548 217 202 15 4,454 60
Aluminium 2,398 178 145 33 1,790 41
Intra-divisional adjustment (659) - - - - -
3,287 395 347 48 6,244 101
Manganese 2,096 639 163 476 1,613 178
Nickel West 1,605 (91) 117 (208) 534 163
Cerro Matoso 595 104 94 10 860 56
Other(v) - (36) 1 (37) 71 -
Total Aluminium,
Manganese and Nickel
from Group production 7,583 1,011 722 289 9,322 498
Third party products 828 18 - 18 - -
Total Aluminium,
Manganese and Nickel 8,411 1,029 722 307 9,322 498 44 38
Statutory adjustments - - - - - - - -
Total Aluminium,
Manganese and Nickel
statutory result 8,411 1,029 722 307 9,322 498 44 38
Year ended
30 June 2013 Net
(Republished) Underlying Underlying operating Capital Exploration Exploration
US$ million Revenue(i) EBITDA D&A EBIT assets expenditure(ii) gross(iii) to profit(iv)
Alumina 1,422 114 239 (125) 3,844 157
Aluminium 2,620 88 127 (39) 2,154 27
Intra-divisional adjustment (638) - - - - -
3,404 202 366 (164) 5,998 184
Manganese 2,113 623 116 507 1,658 375
Nickel West 1,773 (104) 210 (314) 123 280
Cerro Matoso 803 235 79 156 955 50
Other(v) - (79) (14) (65) 75 4
Total Aluminium,
Manganese and Nickel
from Group production 8,093 877 757 120 8,809 893
Third party products 1,185 38 - 38 - -
Total Aluminium,
Manganese and Nickel 9,278 915 757 158 8,809 893 57 53
Statutory adjustments (iv) - - - - - - - -
Total Aluminium,
Manganese and Nickel
statutory result 9,278 915 757 158 8,809 893 57 53
(i) Includes inter-segment revenue of US$5 million (2013: US$20 million).
(ii) Capital expenditure in aggregate comprises US$43 million growth and US$455 million other (2013: US$285 million
growth and US$608 million other).
(iii)Includes US$6 million capitalised exploration (2013: US$8 million).
(iv) Includes US$ nil exploration expenditure previously capitalised, written off as impaired (included in depreciation and
amortisation) (2013: US$4 million).
(v) Predominantly comprises divisional activities and business development.
Group and Unallocated Items
Underlying EBIT expense increased by US$94 million to US$301 million in the 2014 financial year. A one-off
pension plan cost-associated with the closure of the Group’s marketing office in the Netherlands, contributed to
the increase.
The financial information on pages 31 to 52 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 2014 financial year compared with the
2013 financial year, unless otherwise noted. Comparative financial information has been restated for the effect of
new accounting standards and other changes in accounting policies which became effective 1 July 2013, as
described in note 8 to the financial information.
The following abbreviations 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 cubic feet per day (MMcf/d); million tonnes (Mt); million tonnes per annum (Mtpa);
ounces (oz); pounds (lb) thousand barrels of oil equivalent (Mboe); thousand ounces (koz); thousand standard
cubic feet (Mscf); thousand tonnes (kt); thousand tonnes per annum (ktpa); thousand tonnes per day (ktpd);
tonnes (t); and wet metric tonnes (wmt).
The following notes explain the terms used throughout this profit release:
(1) Underlying attributable profit, Underlying EBIT and Underlying EBITDA are used to reflect the underlying
performance of BHP Billiton. Underlying attributable profit is Attributable profit excluding any exceptional
items. Underlying EBIT is earnings before net finance costs, taxation and any exceptional items. Underlying
EBITDA is Underlying EBIT before depreciation, impairments and amortisation of US$9,498 million for the
2014 financial year and US$7,378 million for the 2013 financial year. We believe that Underlying attributable
profit, Underlying EBIT and Underlying EBITDA provide useful information, but should not be considered as
an indication of, or as an alternative to, Attributable profit as an indicator of actual operating performance or
as an alternative to cash flow as a measure of liquidity.
Underlying EBIT includes net finance costs and taxation associated with equity accounted investments of
US$528 million (2013: US$640 million).
Underlying EBITDA includes depreciation, impairments and amortisation associated with equity accounted
investments of US$266 million (2013: US$232 million).
(2) Non-IFRS measures are defined as follows:
• Underlying attributable profit – comprises Profit after taxation attributable to members of BHP Billiton
Group less exceptional items as described in note 2 to the financial information.
• Underlying basic earnings per share – represents basic earnings per share excluding any exceptional
items.
• Underlying EBITDA interest coverage – for the purpose of deriving interest coverage, net interest
comprises Interest on bank loans and overdrafts, Interest on all other borrowings, Finance lease and hire
purchase interest less Interest income.
• Adjusted effective tax rate – comprises Total taxation expense excluding remeasurement of deferred tax
assets associated with the Minerals Resource Rent Tax (MRRT), exceptional items and exchange rate
movements included in taxation expense divided by Profit before taxation and exceptional items.
• Underlying EBIT margin – comprises Underlying EBIT excluding third party product 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.
• Underlying return on capital – represents net profit after tax, excluding exceptional items and net finance
costs (after tax), divided by average capital employed. Capital employed is net assets before net debt.
• Free cash flow – comprises net operating cash flows less net investing cash flows.
• Net debt – comprises Interest bearing liabilities less Cash and cash equivalents.
• 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 associate.
(3) Represents annualised productivity-led volume efficiencies, operating cash cost efficiencies and exploration
and business development savings embedded within the 2014 financial year result. Productivity-led volume
efficiencies refer to volume increases, excluding volume increases from major capital projects, multiplied by
the prior period 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.
US$2.9 billion of productivity gains were achieved in the 2014 financial year. This is in addition to US$3.7
billion of productivity gains reported in the 2013 financial year (subsequently restated to US$4.3 billion due to
an increase of US$0.8 billion on adoption of IFRS 10 and IFRS 11, and a decrease of US$0.2 billion due to
the inclusion of previously classified one-off items).
(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) Simpler portfolio includes: Western Australia Iron Ore, Samarco, Queensland Coal, NSW Energy Coal,
Cerrejón, Escondida, Olympic Dam, Pampa Norte, Antamina, Onshore US, Shenzi, Mad Dog, Atlantis,
Angostura, North West Shelf, Bass Strait, Pyrenees, Macedon and the Jansen project.
(6) Represents planned annualised volume and controllable cash cost productivity gains to be delivered from our
core assets only, relative to the 2014 financial year.
(7) Underlying payout ratio – represents dividends and buy-backs, divided by Underlying attributable profit.
(8) Refers to copper equivalent production based on average realised prices for the 2013 financial year.
(9) Represents the percentage change in production from the 2014 financial year, excluding sold operations
(Liverpool Bay, South Midland and Pinto Valley).
(10) Hay Point Stage Three Expansion project on revised schedule and budget.
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
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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 Underlying attributable profit, Underlying basic earnings per share,
Underlying EBITDA interest coverage, Adjusted effective tax rate, Underlying EBIT margin, Underlying EBITDA
margin, Underlying return on capital, Free cash flow, Net debt and Net operating assets. 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,
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Members of the BHP Billiton Group which is headquartered in Australia
BHP Billiton Group
Financial Information
For the year ended 30 June 2014
Contents
Financial Information
Consolidated Income Statement
Consolidated Statement of Comprehensive Income
Consolidated Balance Sheet
Consolidated Cash Flow Statement
Consolidated Statement of Changes in Equity
Notes to the Financial Information
The financial information included in this document for the year ended 30 June 2014 is unaudited and has been
derived from the draft financial report of the BHP Billiton Group for the year ended 30 June 2014. The financial
information does not constitute the Group’s full financial statements for the year ended 30 June 2014, which will
be approved by the Board, reported on by the auditors, and subsequently filed with the UK Registrar of
Companies and the Australian Securities and Investments Commission.
The financial information set out on pages 31 to 52 for the year ended 30 June 2014 has been prepared on the
basis of accounting policies and methods of computation consistent with those applied in the 30 June 2013
financial statements contained within the Annual Report of the BHP Billiton Group, with the exception of new
accounting standards and interpretations which became effective from 1 July 2013; and for the effects of other
voluntary changes in accounting policy as described in note 8 to the financial information.
The comparative figures for the financial years ended 30 June 2013 and 30 June 2012 are not the statutory
accounts of the BHP Billiton Group for those financial years. Those accounts have been reported on by the
company’s auditor and delivered to the Registrar of Companies. The reports of the auditor were (i) unqualified, (ii)
did not include a reference to any matters to which the auditor drew attention by way of emphasis without
qualifying the reports and (iii) did not contain a statement under Section 498(2) or (3) of the UK Companies Act
2006.
All amounts are expressed in US dollars unless otherwise stated. The BHP Billiton Group’s presentation currency
and the functional currency of the majority of its operations is US dollars as this is the principal currency of the
economic environment in which it operates.
Where applicable, comparative figures have been adjusted to disclose them on the same basis as the current
period figures. Amounts in this financial information have, unless otherwise indicated, been rounded to the
nearest million dollars.
Consolidated Income Statement
for the year ended 30 June 2014
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
US$M US$M US$M
Notes Restated Restated
Revenue
Group production 64,227 63,067 66,969
Third party products 2,979 2,886 3,508
Revenue 1 67,206 65,953 70,477
Other income 1,524 3,947 898
Expenses excluding net finance costs (46,513) (50,040) (48,644)
Share of operating profit of equity accounted investments 3 1,195 1,142 1,869
Profit from operations 23,412 21,002 24,600
Comprising:
Group production 23,368 20,875 24,466
Third party products 44 127 134
23,412 21,002 24,600
Financial expenses (1,273) (1,384) (836)
Financial incomes 97 108 168
Net finance costs 4 (1,176) (1,276) (668)
Profit before taxation 22,236 19,726 23,932
Income tax expense (6,538) (5,714) (7,053)
Royalty-related taxation (net of income tax benefit) (474) (1,192) (262)
Total taxation expense 5 (7,012) (6,906) (7,315)
Profit after taxation 15,224 12,820 16,617
Attributable to non-controlling interests 1,392 1,597 1,144
Attributable to members of BHP Billiton Group 13,832 11,223 15,473
Basic earnings per ordinary share (cents) 6 260.0 210.9 290.7
Diluted earnings per ordinary share (cents) 6 259.1 210.2 289.4
Dividends per ordinary share – paid during the period (cents) 7 118.0 114.0 110.0
Dividends per ordinary share – determined in respect of the period
(cents) 7 121.0 116.0 112.0
The accompanying notes form part of this financial information.
Consolidated Statement of Comprehensive Income
for the year ended 30 June 2014
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
US$M US$M US$M
Restated Restated
Profit after taxation 15,224 12,820 16,617
Other comprehensive income
Items that may be reclassified subsequently to the income statement:
Available for sale investments:
Net valuation losses taken to equity (15) (101) (32)
Net valuation gains transferred to the income statement (14) (1) (2)
Cash flow hedges:
Gains/(losses) taken to equity 681 223 (320)
(Gains)/losses transferred to the income statement (678) 73 205
Exchange fluctuations on translation of foreign operations taken to equity (1) 2 19
Tax recognised within other comprehensive income 3 (76) 23
Total items that may be reclassified subsequently to the income statement (24) 120 (107)
Items that will not be reclassified to the income statement:
Actuarial gains/(losses) on pension and medical schemes 57 61 (250)
Tax recognised within other comprehensive income 12 (16) 66
Total items that will not be reclassified to the income statement 69 45 (184)
Total other comprehensive income/(loss) 45 165 (291)
Total comprehensive income 15,269 12,985 16,326
Attributable to non-controlling interests 1,392 1,599 1,146
Attributable to members of BHP Billiton Group 13,877 11,386 15,180
The accompanying notes form part of this financial information.
Consolidated Balance Sheet
as at 30 June 2014
30 June 2014 30 June 2013
US$M US$M
Restated
ASSETS
Current assets
Cash and cash equivalents 8,803 5,677
Trade and other receivables 6,741 6,310
Other financial assets 87 161
Inventories 6,013 5,821
Assets classified as held for sale – 286
Current tax assets 318 267
Other 334 431
Total current assets 22,296 18,953
Non-current assets
Trade and other receivables 1,867 1,998
Other financial assets 2,349 1,719
Inventories 463 619
Property, plant and equipment 108,787 100,565
Intangible assets 5,439 5,496
Investments accounted for using the equity method 3,664 3,675
Deferred tax assets 6,396 6,069
Other 152 84
Total non-current assets 129,117 120,225
Total assets 151,413 139,178
LIABILITIES
Current liabilities
Trade and other payables 10,145 10,860
Interest bearing liabilities 4,262 5,088
Liabilities classified as held for sale – 220
Other financial liabilities 16 210
Current tax payable 919 1,158
Provisions 2,504 2,372
Deferred income 218 231
Total current liabilities 18,064 20,139
Non-current liabilities
Trade and other payables 113 286
Interest bearing liabilities 30,327 28,099
Other financial liabilities 303 582
Deferred tax liabilities 7,066 6,312
Provisions 9,891 8,178
Deferred income 267 291
Total non-current liabilities 47,967 43,748
Total liabilities 66,031 63,887
Net assets 85,382 75,291
EQUITY
Share capital – BHP Billiton Limited 1,186 1,186
Share capital – BHP Billiton Plc 1,069 1,069
Treasury shares (587) (540)
Reserves 2,927 1,970
Retained earnings 74,548 66,982
Total equity attributable to members of BHP Billiton Group 79,143 70,667
Non-controlling interests 6,239 4,624
Total equity 85,382 75,291
The accompanying notes form part of this financial information.
Consolidated Cash Flow Statement
for the year ended 30 June 2014
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
US$M US$M US$M
Restated Restated
Operating activities
Profit before taxation 22,236 19,726 23,932
Adjustments for:
Non-cash or non-operating exceptional items (551) 1,893 3,417
Depreciation and amortisation expense 8,701 7,031 6,431
Net gain on sale of non-current assets (95) (46) (118)
Impairments of property, plant and equipment, financial assets and intangibles 797 330 100
Employee share awards expense 247 210 270
Net finance costs 1,176 1,276 668
Share of operating profit of equity accounted investments (1,195) (1,142) (1,869)
Other (83) (21) (376)
Changes in assets and liabilities:
Trade and other receivables (252) 1,037 1,755
Inventories (54) (70) 16
Trade and other payables 77 (767) (187)
Net other financial assets and liabilities (49) 119 (27)
Provisions and other liabilities 429 (783) (1,025)
Cash generated from operations 31,384 28,793 32,987
Dividends received 34 11 10
Dividends received from equity accounted investments 1,250 710 712
Interest received 136 140 221
Interest paid (975) (926) (633)
Income tax refunded 852 - 530
Income tax paid (6,445) (7,618) (7,492)
Royalty-related taxation refunded 216 (956) (1,076)
Royalty-related taxation paid (1,088) 20,154 25,259
Net operating cash flows 25,364 20,154 25,259
Investing activities
Purchases of property, plant and equipment (15,993) (22,243) (18,637)
Exploration expenditure (1,010) (1,351) (2,493)
Exploration expenditure expensed and included in operating cash flows 716 1,047 1,644
Purchase of intangibles (192) (400) (219)
Investment in financial assets (1,193) (475) (471)
Investment in subsidiaries, operations and joint operations, net of their cash – – (12,556)
Investment in equity accounted investments (44) (84) (83)
Cash outflows from investing activities (17,716) (23,506) (32,815)
Proceeds from sale of property, plant and equipment 114 2,338 146
Proceeds from financial assets 956 240 178
Proceeds from divestment of subsidiaries, operations and joint operations, net of their
cash 812 502 6
Proceeds from sale or partial sale of equity accounted investments – 1,700 –
Net investing cash flows (15,834) (18,726) (32,485)
Financing activities
Proceeds from interest bearing liabilities 6,251 9,157 12,817
Proceeds/(settlements) from debt related instruments 37 14 (180)
Repayment of interest bearing liabilities (7,198) (2,014) (3,993)
Proceeds from ordinary shares 14 21 21
Contributions from non-controlling interests 1,435 73 101
Purchase of shares by Employee Share Ownership Plan (ESOP) trusts (368) (445) (424)
Share buy-back – BHP Billiton Plc – – (83)
Dividends paid (6,387) (6,167) (5,877)
Dividends paid to non-controlling interests (252) (837) (343)
Net financing cash flows (6,468) (198) 2,039
Net increase/(decrease) in cash and cash equivalents 3,062 1,230 (5,187)
Cash and cash equivalents, net of overdrafts, at the beginning of the financial year 5,667 4,454 9,671
Foreign currency exchange rate changes on cash and cash equivalents 23 (17) (30)
Cash and cash equivalents, net of overdrafts, at the end of the financial year 8,752 5,667 4,454
The accompanying notes form part of this financial information.
Consolidated Statement of Changes in Equity
for the year ended 30 June 2014
For the year ended 30 June 2014 Attributable to members of the BHP Billiton
Group
US$M Share Share Treasury Reserves Retained Total equity Non- Total
capital capital shares earnings attributable controlling equity
– BHP – BHP to members interests
Billiton Billiton of BHP
Limited Plc Billiton
Group
Balance as at 1 July 2013 1,186 1,069 (540) 1,970 66,982 70,667 4,624 75,291
Profit after taxation - - - - 13,832 13,832 1,392 15,224
Other comprehensive income:
Net valuation losses on available for sale
investments taken to equity - - - (15) - (15) - (15)
Net valuation gains on available for sale
investments transferred to the income
statement - - - (14) - (14) - (14)
Gains on cash flow hedges taken to equity - - - 681 - 681 - 681
Gains on cash flow hedges transferred to the
income statement - - - (678) - (678) - (678)
Exchange fluctuations on translation of foreign
operations taken to equity - - - (1) - (1) - (1)
Actuarial gains on pension and medical
schemes - - - - 57 57 - 57
Tax recognised within other comprehensive
income - - - 3 12 15 - 15
Total comprehensive income - - - (24) 13,901 13,877 1,392 15,269
Transactions with owners:
Purchase of shares by ESOP Trusts - - (368) - - (368) - (368)
Employee share awards exercised net of
employee contributions - - 321 (221) (91) 9 - 9
Employee share awards forfeited - - - (32) 32 - - -
Accrued employee entitlement for unexercised
awards - - - 247 - 247 - 247
Distribution to option holders - - - (2) - (2) (2) (4)
Dividends - - - - (6,276) (6,276) (252) (6,528)
Equity contributed - - - 989 - 989 477 1,466
Balance as at 30 June 2014 1,186 1,069 (587) 2,927 74,548 79,143 6,239 85,382
The accompanying notes form part of this financial information.
Consolidated Statement of Changes in Equity
for the year ended 30 June 2014 (continued)
For the year ended 30 June 2013 Attributable to members of the BHP Billiton Group
US$M Share Share Treasury Reserves Retained Total equity Non- Total
Restated capital capital shares earnings attributable controlling equity
– BHP – BHP to members interests
Billiton Billiton of BHP
Limited Plc Billiton
Group
Balance as at 1 July 2012 1,186 1,069 (533) 1,912 61,892 65,526 3,789 69,315
Profit after taxation - - - - 11,223 11,223 1,597 12,820
Other comprehensive income:
Net valuation (losses)/gains on available for
sale investments taken to equity - - - (103) - (103) 2 (101)
Net valuation gains on available for sale - - - (1) - (1) - (1)
investments transferred to the income
statement
Gains on cash flow hedges taken to equity - - - 223 - 223 - 223
Losses on cash flow hedges transferred to
the income statement - - - 73 - 73 - 73
Exchange fluctuations on translation of
foreign operations taken to equity - - - 2 - 2 - 2
Actuarial gains on pension and medical
schemes - - - - 60 60 1 61
Tax recognised within other comprehensive
income - - - (117) 26 (91) (1) (92)
Total comprehensive income - - - 77 11,309 11,386 1,599 12,985
Transactions with owners:
Purchase of shares by ESOP Trusts - - (445) - - (445) - (445)
Employee share awards exercised net of
employee contributions - - 438 (243) (178) 17 - 17
Employee share awards forfeited - - - (17) 17 - - -
Accrued employee entitlement for
unexercised awards - - - 210 - 210 - 210
Issue of share options to non-controlling
interests - - - 49 - 49 - 49
Dividends - - - - (6,076) (6,076) (837) (6,913)
Equity contributed - - - - - - 73 73
Divestments of equity accounted investment - - - (18) 18 - - -
Balance as at 30 June 2013 1,186 1,069 (540) 1,970 66,982 70,667 4,624 75,291
Consolidated Statement of Changes in Equity
for the year ended 30 June 2014 (continued)
For the year ended 30 June 2012 Attributable to members of the BHP Billiton Group
US$M Share Share Treasury Reserves Retained Total equity Non- Total
Restated capital capital shares earnings attributable controlling equity
– BHP – BHP to members interests
Billiton Billiton of BHP
Limited Plc Billiton
Group
Balance as at 1 July 2011 1,183 1,070 (623) 2,001 52,731 56,362 2,825 59,187
Profit after taxation - - - - 15,473 15,473 1,144 16,617
Other comprehensive income:
Net valuation losses on available for sale
investments taken to equity - - - (32) - (32) - (32)
Net valuation gains on available for sale
investments transferred to the income
statement - - - (2) - (2) - (2)
Losses on cash flow hedges taken to equity - - - (320) - (320) - (320)
Losses on cash flow hedges transferred to
the income statement - - - 205 - 205 - 205
Exchange fluctuations on translation of
foreign operations taken to equity - - - 19 - 19 - 19
Actuarial losses on pension and medical
schemes - - - - (253) (253) 3 (250)
Tax recognised within other comprehensive
income - - - (33) 123 90 (1) 89
Total comprehensive income - - - (163) 15,343 15,180 1,146 16,326
Transactions with owners:
Proceeds from the issue of shares 3 - - - - 3 - 3
BHP Billiton Plc shares cancelled - (1) 83 1 (83) - - -
Purchase of shares by ESOP Trusts - - (424) - - (424) - (424)
Employee share awards exercised net of (189) (213) 29 - 29
employee contributions - - 431
Employee share awards forfeited - - - (8) 8 - - -
Accrued employee entitlement for 270 - 270 - 270
unexercised awards - - -
Dividends - - - - (5,894) (5,894) (343) (6,237)
Equity contributed - - - - - - 161 161
Balance as at 30 June 2012 1,186 1,069 (533) 1,912 61,892 65,526 3,789 69,315
The accompanying notes form part of this financial information.
Notes to the Financial Information
1. Segment reporting
The Group operates five 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 and Potash Exploration, development and production of oil and gas
Potash pre-development
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
Aluminium, Manganese and Nickel Mining of bauxite, refining of bauxite into alumina and smelting of alumina into
aluminium metal
Mining of manganese ore and production of manganese metal and alloys
Mining and production of nickel products
Group and unallocated items represent Group centre functions, unallocated operations and consolidation
adjustments. 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.
1. Segment reporting (continued)
Year ended 30 June 2014 Petroleum Copper Iron Ore Coal Aluminium, Group and BHP
US$M and Potash Manganese unallocated Billiton
and Nickel items/ Group
eliminations (f)
Revenue
Group production 14,022 12,838 20,882 8,659 7,583 - 63,984
Third party products 437 1,030 130 456 823 103 2,979
Rendering of services 112 - 131 - - - 243
Inter-segment revenue 262 - 213 - 5 (480) -
Total revenue(a) 14,833 13,868 21,356 9,115 8,411 (377) 67,206
Underlying EBITDA(b) 9,615 6,586 13,531 1,717 1,029 (119) 32,359
Depreciation and amortisation (3,951) (1,418) (1,464) (1,039) (670) (159) (8,701)
Impairment (losses)/reversals (377) (88) 35 (292) (52) (23) (797)
Underlying EBIT(b) 5,287 5,080 12,102 386 307 (301) 22,861
Comprising:
Group production 5,288 4,634 11,498 218 289 (305) 21,622
Third party products 3 8 (3) 18 18 - 44
Share of operating profit of
equity accounted investments (4) 438 607 150 - 4 1,195
Underlying EBIT(b) 5,287 5,080 12,102 386 307 (301) 22,861
Net finance costs(c) (1,176)
Exceptional items(d) 551
Profit before taxation 22,236
Capital expenditure 6,423 3,757 2,949 2,345 498 21 15,993
Investments accounted for
using the equity method(e) 115 1,386 1,069 1,089 - 5 3,664
Total assets(e) 47,046 24,690 27,412 18,863 12,713 20,689 151,413
Total liabilities (e) 7,532 2,459 4,022 4,563 3,391 44,064 66,031
1. Segment reporting (continued)
Year ended 30 June 2013 Petroleum Copper Iron Ore Coal Aluminium, Group and BHP
US$M and Potash Manganese unallocated Billiton
and Nickel items/ Group
eliminations
(f)
Revenue
Group production 12,951 13,837 18,331 9,310 8,093 326 62,848
Third party products 175 700 86 585 1,165 175 2,886
Rendering of services 98 - 121 - - - 219
Inter-segment revenue - - 55 - 20 (75) -
Total revenue (a) 13,224 14,537 18,593 9,895 9,278 426 65,953
Underlying EBITDA (b) 8,910 6,885 12,113 1,480 915 5 30,308
Depreciation and amortisation (3,068) (1,197) (917) (885) (772) (192) (7,031)
Impairment (losses)/reversals (206) (49) (87) - 15 (20) (347)
Underlying EBIT (b) 5,636 5,639 11,109 595 158 (207) 22,930
Comprising:
Group production 5,616 5,181 10,565 410 120 (231) 21,661
Third party products 11 3 31 44 38 - 127
Share of operating profit of
equity accounted
investments 9 455 513 141 - 24 1,142
Underlying EBIT (b) 5,636 5,639 11,109 595 158 (207) 22,930
Net finance costs (c) (1,276)
Exceptional items (d) (1,928)
Profit before taxation 19,726
Capital expenditure 7,675 3,930 5,979 3,626 893 140 22,243
Investments accounted for
using the equity method(e) 130 1,351 1,044 1,150 - - 3,675
Total assets(e) 44,383 22,623 25,877 17,568 12,092 16,635 139,178
Total liabilities(e) 6,858 2,549 3,751 4,343 3,283 43,103 63,887
1. Segment reporting (continued)
Year ended 30 June 2012 Petroleum Copper Iron Ore Coal Aluminium, Group and BHP
US$M and Potash Manganese unallocated Billiton
and Nickel items/ Group
eliminations
(f)
Revenue
Group production 12,617 13,090 20,171 11,638 8,334 706 66,556
Third party products 230 463 86 856 1,563 310 3,508
Rendering of services 86 - 309 18 - - 413
Inter-segment revenue - - 39 - 14 (53) -
Total revenue(a) 12,933 13,553 20,605 12,512 9,911 963 70,477
Underlying EBITDA(b) 9,097 6,203 14,815 3,340 809 353 34,617
Depreciation and amortisation (3,045) (960) (771) (730) (811) (114) (6,431)
Impairment (losses)/reversals (19) 70 - 2 (22) (131) (100)
Underlying EBIT(b) 6,033 5,313 14,044 2,612 (24) 108 28,086
Comprising:
Group production 6,023 4,800 13,104 2,195 (43) 4 26,083
Third party products 3 (9) 31 90 19 - 134
Share of operating profit of
equity accounted
investments 7 522 909 327 - 104 1,869
Underlying EBIT(b) 6,033 5,313 14,044 2,612 (24) 108 28,086
Net finance costs(c) (668)
Exceptional items(d) (3,486)
Profit before taxation 23,932
Capital expenditure 5,573 3,518 4,458 3,103 1,941 44 18,637
Investments accounted for
using the equity method(e) 129 1,073 876 1,103 - - 3,181
Total assets(e) 39,937 20,417 21,214 15,635 16,759 15,239 129,201
Total liabilities(e) 6,354 3,696 3,839 4,972 3,632 37,393 59,886
(a) Revenue not attributable to reportable segments comprises the sale of freight and fuel to third parties, as well as
revenues from unallocated operations described in footnote (f).
(b) Underlying EBIT is earnings before net finance costs, taxation and any exceptional items. Underlying EBIT is reported
net of net finance costs and taxation associated with equity accounted investments. Underlying EBITDA is Underlying
EBIT before depreciation, impairments and amortisation.
(c) Refer to note 4 Net finance costs.
(d) Refer to note 2 Exceptional items.
(e) Total segment assets and liabilities of businesses represent operating assets and 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 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 associate.
(f) Includes the Group’s diamonds business (divested effective 10 April 2013), interest in titanium minerals (divested
effective 3 September 2012), non-Potash corporate costs incurred by the former Diamonds and Specialty Products
business, consolidation adjustments and unallocated items.
2. Exceptional items
Year ended 30 June 2014 Gross Tax Net
US$M US$M US$M
Exceptional items by category
Sale of Pinto Valley 551 (166) 385
551 (166) 385
Sale of Pinto Valley:
On 11 October 2013, the Group announced it had completed the sale of its Pinto Valley mining operation for cash
consideration of US$653 million, after working capital adjustments. A gain on sale of US$385 million (after tax
expense) was recognised in the year ended 30 June 2014.
Gross Tax Net
Year ended 30 June 2014 US$M US$M US$M
Exceptional items by category
Sale of Yeelirrie uranium deposit 420 - 420
Sale of Richards Bay Minerals 1,212 (183) 1,029
Sale of diamonds business (97) (42) (139)
Sale of East and West Browse Joint Ventures 1,539 (188) 1,351
Impairment of Nickel West assets (1,698) 454 (1,244)
Impairment of Worsley assets (2,190) 559 (1,631)
Impairment of Permian Basin assets (266) 99 (167)
Other impairments arising from capital project review (1,006) 291 (715)
Newcastle steelworks rehabilitation 158 (47) 111
(1,928) 943 (985)
Sale of Yeelirrie uranium deposit:
On 27 August 2012, the Group announced the sale of its wholly owned Yeelirrie uranium deposit and the
transaction was completed on 19 December 2012. A gain on sale of US$420 million was recognised in the year
ended 30 June 2013, while the associated tax expense was offset by the recognition of deferred tax benefits on
available tax losses.
Sale of Richards Bay Minerals:
On 7 September 2012, the Group announced it had completed the sale of its 37.76 per cent effective interest in
Richards Bay Minerals. A gain on sale of US$1,029 million (after tax expense) was recognised in the year ended
30 June 2013.
Sale of diamonds business:
On 13 November 2012, the Group announced the sale of its diamonds business, comprising its interests in the
EKATI Diamond Mine and Diamond Marketing operations. The transaction was completed on 10 April 2013 for
an aggregate cash consideration of US$553 million (after adjustments). An impairment charge of US$139 million
(after tax expense) was recognised based on the final consideration.
Sale of East and West Browse Joint Ventures:
On 12 December 2012, the Group signed a definitive agreement to sell its 8.33 per cent interest in the East
Browse Joint Venture and 20 per cent interest in the West Browse Joint Venture. A gain on sale of US$1,539
million was recognised in the year ended 30 June 2013. The associated tax expense of US$462 million was
partly offset by the recognition of deferred tax benefits on available tax losses of US$274 million. The transaction
was completed on 7 June 2013.
2. Exceptional items (continued)
Impairment of Nickel West assets:
As a result of expected continued strength in the Australian dollar and weak nickel prices the Group recognised
an impairment charge of US$1,244 million (after tax benefit) in the year ended 30 June 2013.
Impairment of Worsley assets:
The Group recognised an impairment of assets at Worsley as a result of expected continued strength in the
Australian dollar and weak alumina prices. A total impairment charge of US$1,631 million (after tax benefit) was
recognised in the year ended 30 June 2013.
Impairment of Permian Basin assets:
An impairment charge of US$167 million (after tax benefit) was recognised as the performance of specific
evaluation wells in certain areas of the Permian Basin (US) do not support economic development.
Other impairments arising from capital project review:
In the year ended 30 June 2013, WAIO refocused its attention on the capital efficient expansion opportunity that
exists within the Port Hedland inner harbour and all early works associated with the outer harbour development
option were suspended. This revision to the WAIO development sequence and the change in status of other
minor capital projects across the Group has resulted in the recognition of impairment charges of US$639 million
(after tax benefit) and other restructuring costs of US$76 million (after tax benefit) in the year ended 30 June
2013.
Newcastle steelworks rehabilitation:
The Group recognised a decrease of US$158 million (before tax expense) to its rehabilitation obligations in respect of former
operations at the Newcastle steelworks (Australia). This followed the completion of the Hunter River Remediation Project
and reaching agreement with the Environment Protection Authority in March 2013 regarding the necessary scope of work to
repeal the Environmental Classification at Steel River.
Gross Tax Net
Year ended 30 June 2012 US$M US$M US$M
Exceptional items by category
Impairment of Fayetteville goodwill and other assets (2,835) 996 (1,839)
Impairment of Nickel West goodwill and other assets (449) 94 (355)
Suspension or early closure of operations and the change
in status of specific projects (a) (502) 108 (394)
Settlement of insurance claims (a) 300 (90) 210
Recognition of deferred tax assets on enactment of MRRT and PRRT extension legislation in
Australia – 637 637
(3,486) 1,745 (1,741)
(a) Includes amounts attributable to non-controlling interests of US$(34) million (US$7 million tax expense).
Impairment of Fayetteville goodwill and other assets:
As a result of the fall in United States domestic gas prices and the Company’s decision to adjust its development
plans, the Group recognised impairments of goodwill and other assets in relation to its Fayetteville shale gas
assets. A total impairment charge of US$1,839 million (after tax benefit) was recognised in the year ended 30
June 2012.
2. Exceptional items (continued)
Impairment of Nickel West goodwill and other assets:
The Group recognised impairments of goodwill and other assets at Nickel West as a result of the continued
downturn in the nickel price and margin deterioration. A total impairment charge of US$355 million (after tax
benefit) was recognised in the year ended 30 June 2012.
Suspension or early closure of operations and the change in status of specific projects:
As part of our regular portfolio review, various operations and projects around the Group were either suspended,
closed early or changed in status. These included: the change in status of the Olympic Dam expansion project;
the temporary suspension of production at TEMCO and the permanent closure of the Metalloys South Plant in
South Africa; the indefinite cessation of production at Norwich Park; and the suspension of other minor capital
projects. As a result, impairment charges of US$338 million (after tax benefit), idle capacity costs and inventory
write-down of US$28 million (after tax benefit) and other restructuring costs of US$28 million (after tax benefit)
were recognised in the year ended 30 June 2012.
Settlement of insurance claims:
During 2008, extreme weather across the central Queensland coalfields affected production from the BHP Billiton
Mitsubishi Alliance (BMA) and BHP Billiton Mitsui Coal (BMC) operations. The Group settled insurance claims in
respect of the lost production and insurance claim income of US$210 million (after tax expense) was recognised
in the year ended 30 June 2012.
Recognition of deferred tax assets on enactment of MRRT and PRRT extension legislation in Australia:
The Australian MRRT and PRRT extension legislation were enacted in March 2012. Under the legislation, the
Group is entitled to a deduction against future Minerals Resource Rent Tax (MRRT) and Petroleum Resource
Rent Tax (PRRT) liabilities based on the market value of its coal, iron ore and petroleum assets. A deferred tax
asset, and an associated net income tax benefit of US$637 million, was recognised in the year ended 30 June
2012 to reflect the future deductibility of these market values for MRRT and PRRT purposes, to the extent they
were considered recoverable.
3. Interests in associations and joint venture entities
Major shareholdings in associates Ownership interest at BHP Billiton Group Share of operating profit of equity
and joint venture entities reporting date (a) Accounted investments
30 June 30 June 30 June Year ended Year ended Year ended
2014 2013 2012 30 June 2014 30 June 2013 30 June 2012
% % % US$M US$M US$M
Carbones del Cerrejon LLC 33.33 33.33 33.33 115 117 294
Compañia Minera Antamina SA 33.75 33.75 33.75 476 531 614
Samarco Mineração SA 50 50 50 607 513 909
Other(b) (3) (19) 52
Total 1,195 1,142 1,869
(a) The ownership interest at the Group’s and the associates and joint venture entities’ reporting date are the same. When
the annual financial reporting date is different to the Group’s, financial information is obtained as at 30 June in order to
report on a basis consistent with the Group’s reporting date.
(b) Includes the Group’s effective interest in the Newcastle Coal Infrastructure Group Pty Limited (ownership interest 35.5
per cent; 30 June 2013: 35.5 per cent; 30 June 2012: 35.5 per cent) and other immaterial equity accounted investments.
4. Net finance costs
Year ended 30 June Year ended 30 June Year ended 30 June
2014 2013 2012
US$M US$M US$M
Financial expenses
Interest on bank loans and overdrafts 14 13 19
Interest on all other borrowings (a) 708 965 641
Finance lease and hire purchase interest 55 11 37
Discounting on provisions and other liabilities 475 478 485
Net interest expense on post-retirement employee
benefits 22 19 26
Interest capitalised (b) (182) (290) (272)
Fair value change on hedged loans 328 (505) 345
Fair value change on hedging derivatives (292) 489 (381)
Fair value change on non-hedging derivatives (a) 101 183 (11)
Exchange variations on net debt 44 21 (53)
1,273 1,384 836
Financial income
Interest income (97) (108) (168)
(97) (108) (168)
Net finance costs 1,176 1,276 668
(a) Interest on all other borrowings includes financial income of US$52 million of realised fair value changes on non-hedging
derivatives used to manage interest rate exposures on debt securities (30 June 2013: expense of US$97 million; 30
June 2012: US$ nil). The fair value change on non-hedging derivatives includes only the unrealised fair value changes
on similar instruments. The total fair value changes on non-hedging derivatives amounted to an expense of US$49
million (30 June 2013: expense of US$280 million; 30 June 2012: gain of US$11 million).
(b) Interest has been capitalised at the rate of interest applicable to the specific borrowings financing the assets under
construction or, where financed through general borrowings, at a capitalisation rate representing the average interest
rate on such borrowings. For the year ended 30 June 2014, the capitalisation rate was 1.82 per cent (30 June 2013:
2.24 per cent; 30 June 2012: 2.83 per cent).
5. Taxation
Year ended 30 June Year ended 30 June Year ended 30 June
2014 2013 2012
US$M US$M US$M
Taxation expense attributed to geographical
jurisdiction:
UK taxation (benefit)/expense (44) 84 (70)
Australian taxation expense 4,871 4,512 5,837
Overseas taxation expense 2,185 2,310 1,548
Total taxation expense(a) 7,012 6,906 7,315
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
US$M US$M US$M
Total taxation expense comprises:
Income tax expense
Income tax expense 6,538 5,714 7,053
6,538 5,714 7,053
Total Royalty-related taxation (net of income tax benefit)(b)
Minerals Resource Rent Tax (benefit)/expense (238) 321 (494)
Other royalty-related taxation expense 712 871 756
474 1,192 262
Total taxation expense 7,012 6,906 7,315
5. Taxation (continued)
(a) Total taxation expense including royalty-related taxation, exceptional items and exchange rate movements, was
US$7,012 million, representing an effective tax rate of 31.5 per cent (30 June 2013: 35.0 per cent; 30 June 2012: 30.6
per cent). Exchange rate movements decreased taxation expense by US$24 million, representing a decrease in the
effective tax rate of 0.1 per cent (30 June 2013: increase of US$245 million and 1.2 per cent; 30 June 2012: increase of
US$347 million and 1.4 per cent). Exceptional items, as described in note 2, increased taxation expense by US$166
million (30 June 2013: decrease of US$943 million; 30 June 2012: decrease of US$1,745 million).
(b) Government imposed royalty arrangements calculated by reference to profits, including MRRT, are reported as royalty-
related taxation. Total royalty-related taxation increased taxation expense by US$474 million resulting in an increase in
the effective tax rate of 2.1 per cent (30 June 2013: increase of US$1,192 million and 6.0 per cent; 30 June 2012:
increase of US$262 million and 1.1 per cent). The MRRT reduced taxation expense by US$238 million in the June 2014
financial year (30 June 2013: increase of US$321 million; 30 June 2012: decrease of US$494 million). This included
US$170 million due to the remeasurement of deferred tax assets associated with the MRRT (30 June 2013: increase of
US$207 million; 30 June 2012: initial recognition of deferred tax assets of US$494 million).
6. Earnings per share
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
Basic earnings per ordinary share (cents) 260.0 210.9 290.7
Diluted earnings per ordinary share (cents) 259.1 210.2 289.4
Basic earnings per American Depositary Share (ADS) 520.0 421.8 581.4
(cents) (a)
Diluted earnings per American Depositary Share (ADS) 518.2 420.4 578.8
(cents) (a)
Basic earnings (US$M) 13,832 11,223 15,473
Diluted earnings (US$M) 13,832 11,223 15,473
(a) Each American Depositary Share represents two ordinary shares.
The weighted average number of shares used for the purposes of calculating diluted earnings per share
reconciles to the number used to calculate basic earnings per share as follows:
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
Million Million Million
Weighted average number of shares
Basic earnings per ordinary share denominator 5,321 5,322 5,323
Shares and options contingently issuable under
employee share ownership plans 17 18 23
Diluted earnings per ordinary share denominator 5,338 5,340 5,346
7. Dividends
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
US$M US$M US$M
Dividends paid/payable during the period
BHP Billiton Limited 3,793 3,662 3,559
BHP Billiton Plc – Ordinary shares 2,483 2,404 2,335
– Preference shares(a) – – –
6,276 6,066 5,894
Dividends declared in respect of the period
BHP Billiton Limited 3,887 3,721 3,621
BHP Billiton Plc – Ordinary shares 2,555 2,446 2,376
– Preference shares(a) – – –
6,442 6,167 5,997
(a) 5.5 per cent dividend on 50,000 preference shares of £1 each declared and paid annually (30 June 2013: 5.5 per cent; 30
June 2012: 5.5 per cent).
7. Dividends (continued)
Year ended Year ended Year ended
30 June 2014 30 June 2013 30 June 2012
US cents US cents US cents
Dividends paid during the period (per share)
Prior year final dividend 59.0 57.0 55.0
Interim dividend 59.0 57.0 55.0
118.0 114.0 110.0
Dividends declared in respect of the period (per share)
Interim dividend 59.0 57.0 55.0
Final dividend 62.0 59.0 57.0
121.0 116.0 112.0
Dividends are determined after period end in the announcement of the results for the period. Interim dividends
are determined in February and paid in March. Final dividends are determined in August and paid in September.
Dividends determined are not recorded as a liability at the end of the period to which they relate. Subsequent to
year end, on 19 August 2014, BHP Billiton determined a final dividend of 62.0 US cents per share (US$3,301
million), which will be paid on 23 September 2014 (30 June 2013: final dividend of 59.0 US cents per share –
US$3,147 million; 30 June 2012: final dividend of 57.0 US cents per share – US$3,049 million).
BHP Billiton Limited dividends for all periods presented are, or will be, fully franked based on a tax rate of 30 per
cent.
2014 2013 2012
US$M US$M US$M
Franking credits as at 30 June 13,419 10,516 7,494
Franking (debits)/credits arising from the (29) 824 2,547
(refund)/payment of current tax
Total franking credits available (a) 13,390 11,340 10,041
(b) The payment of the final 2014 dividend determined after 30 June 2014 will reduce the franking account balance by
US$853 million.
8. Impact of new accounting standards and change in policies
Comparative financial information for the years ended 30 June 2013 and 30 June 2012 has been restated for the
effects of new accounting standards and interpretations which are effective in the financial year commencing from
1 July 2013 relating to:
- IFRS 10/AASB 10 ‘Consolidated Financial Statements’ which is a replacement of IAS 27/AASB 127
‘Consolidated and Separate Financial Statements’;
- IFRS 11/AASB 11 ‘Joint Arrangements’ which is a replacement of IAS 31/AASB 131 ‘Joint Ventures’;
- IAS 28 ‘Investments in Associates and Joint Ventures’ which is a replacement of IAS 28 ‘Accounting for
Investments in Associates’;
- IFRIC 20 ‘Stripping Costs in the Production Phase of a Surface Mine’;
- IFRS 13/AASB 13 ‘Fair Value Measurement’; and
- Amendments to IAS 19/AASB 119 ‘Employee Benefits’.
The Group has also changed its Exploration and Evaluation Expenditure policy from 1 July 2013 such that all
acquisitions of exploration leases are classified as intangible exploration assets or tangible exploration assets
based on the nature of the assets acquired.
For further detail of the nature and the impact of these changes, on comparative financial information, refer to the
Financial Report for the half year ended 31 December 2013.
9. Subsequent events
The Group announced on 19 August 2014 that it plans to demerge a selection of its aluminium, coal, nickel, silver
and manganese assets to create an independent metals and mining company. This includes BHP Billiton’s
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.
It is intended that the new company would be listed on the Australian Securities Exchange with a secondary
listing on the Johannesburg Stock Exchange. A final Board decision will only be made once the necessary
government, taxation, regulatory and other third party approvals are secured on satisfactory terms. Once the
necessary approvals are in place, shareholders will have the opportunity to vote on the proposed demerger.
As numerous steps are required to enable the demerger to proceed, the relevant businesses have not been
classified as held for sale or distribution as at 30 June 2014. Subject to final Board approval to proceed,
shareholder approval and the receipt of satisfactory third party approvals, the demerger is expected to be
completed in the first half of the 2015 calendar year.
Summarised financial information as at 30 June 2014 and for the year ended 30 June 2014 of the businesses
included in the proposed demerger is provided below:
Year ended
30 June 2014
US$M
Current assets 2,860
Non-current assets 14,619
Current liabilities 1,897
Non-current liabilities 3,950
Net assets 11,632
Attributable to non-controlling interests 867
Attributable to members of BHP Billiton Group 10,765
Revenue 10,444
Depreciation and amortisation 1,303
Profit before interest and taxation 764
Net operating cash inflows 1,658
Net investing cash outflows 700
Transaction costs incurred 45
The demerger will be recognised as a reduction in equity at the fair value of the shares in the demerged company
distributed to shareholders. A gain or loss will arise on the difference between the fair value of those shares and
the net assets of the demerged businesses determined at the date of the demerger, which will include the fair
value step-up on the Manganese business described below, less any transaction costs. Transaction costs will
mainly comprise stamp duty, professional fees and separation and establishment costs.
In contemplation of the proposed demerger, BHP Billiton and Anglo American have agreed to make certain
changes to the agreement which governs their interests in the Manganese business. BHP Billiton manages and
owns 60 per cent of the Manganese businesse with Anglo American owning the remaining 40 per cent.
Subject to obtaining the required approvals for the agreement will result in BHP Billiton and Anglo American
agreeing to share joint control of the Manganese business. BHP Billiton will discontinue consolidation of the
Manganese businesse and account for its 60 per cent interest as an equity accounted joint venture. BHP Billiton
will therefore derecognise the existing carrying amounts of all assets, liabilities and the non-controlling interest in
the Manganese business attributed to Anglo American and initially record its retained 60 per cent interest at fair
value. The remeasurement at fair value will give rise to an estimated gain of approximately US$2 billion.
9. Subsequent events (continued)
Other than the matters outlined above or elsewhere in this news release, no matters or circumstances have
arisen since the end of the financial 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.
Date: 19/08/2014 09:04:00 Produced by the JSE SENS Department. The SENS service is an information dissemination service administered by the JSE Limited ('JSE').
The JSE does not, whether expressly, tacitly or implicitly, represent, warrant or in any way guarantee the truth, accuracy or completeness of
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