Royal Dutch Shell plc: 4th Quarter and Full Year 2011 Unaudited Results
THE HAGUE, The Netherlands, February 2, 2012 /PRNewswire/ –
- Royal Dutch Shell's (NYSE:RDS.A) (NYSE:RDS.B) fourth quarter 2011
earnings, on a current cost of supplies (CCS) basis (see Note 1), were $6.5 billion
compared with $5.7 billion in the same quarter a year ago. Full year 2011 CCS earnings
were $28.6 billion compared with $18.6 billion in 2010.
- Fourth quarter 2011 CCS earnings excluding identified items (see page 5) were
$4.8 billion compared with $4.1 billion in the fourth quarter 2010, an increase of
18%. Full year 2011 CCS earnings excluding identified items were $24.7 billion
compared with $18.1 billion in 2010.
- Basic CCS earnings per share excluding identified items for the fourth quarter
2011 increased by 16% versus the same quarter a year ago. Basic CCS earnings per share
excluding identified items for the full year 2011 increased by 35% versus a year ago.
- Cash flow from operating activities was $6.5 billion for the fourth quarter
2011 and $36.8 billion for the full year. Excluding net working capital movements,
cash flow from operating activities was $7.2 billion for the fourth quarter 2011 and
$43.2 billion for the full year.
- Gearing was 13.1% at the end of 2011 versus 17.1% at the end of 2010.
- A fourth quarter 2011 dividend has been announced of $0.42 per ordinary share
and $0.84 per American Depositary Share (ADS), unchanged from the US dollar dividend
per share and per ADS for the same period in 2010.
- A first quarter 2012 dividend is expected to be declared at $0.43 per share
and $0.86 per ADS, an increase of 2% compared with the first quarter 2011 US dollar
dividend.
Summary of unaudited results
Quarters $ million Full year
Q4
2011 Q3 2011 Q4 2010 %[1] 2011 2010 %
Income attributable to
6,500 6,976 6,790 -4 shareholders 30,918 20,127 +54
Current cost of supplies
(CCS) adjustment for
(41) 270 (1,094) Downstream (2,293) (1,484)
6,459 7,246 5,696 +13 CCS earnings 28,625 18,643 +54
1,613 245 1,586 Less: Identified items[2] 3,938 570
CCS earnings excluding
4,846 7,001 4,110 +18 identified items 24,687 18,073 +37
Of which:
5,107 5,435 3,440 Upstream 20,600 14,442
(278) 1,818 482 Downstream 4,274 3,873
Corporate and
17 (252) 188 Non-controlling interest (187) (242)
Cash flow from operating
6,465 11,645 5,456 +18 activities 36,771 27,350 +34
Basic CCS earnings per
1.04 1.16 0.93 +12 share ($) 4.61 3.04 +52
Basic CCS earnings per ADS
2.08 2.32 1.86 ($) 9.22 6.08
Basic CCS earnings per
share excl. identified
0.78 1.12 0.67 +16 items ($) 3.97 2.95 +35
Basic CCS earnings per ADS
1.56 2.24 1.34 excl. identified items ($) 7.94 5.90
0.42 0.42 0.42 - Dividend per share ($) 1.68 1.68 -
0.84 0.84 0.84 Dividend per ADS ($) 3.36 3.36
[1] Q4 on Q4 change.
[2] See page 5.
The information in these quarterly and full year results reflects the consolidated
financial position and results of Royal Dutch Shell plc (“Royal Dutch Shell”). All amounts
shown throughout this report are unaudited. Company No. 4366849, Registered Office: Shell
Centre, London, SE1 7NA, England, UK.
Royal Dutch Shell Chief Executive Officer Peter Voser commented:
“Our fourth quarter results were impacted by a sharp downturn in industry refining
margins and North American natural gas prices. The global economy and energy markets are
likely to see continued high volatility. Despite the near-term uncertainties, Shell’s
focus remains on through-cycle investment for sustainable growth.
I am pleased with our delivery in 2011, focusing on improving our operating
performance and ramping up our growth projects. We have made good progress with portfolio
development during 2011, with new opportunities in global gas, liquids-rich shales and
exploration, alongside some $7.5 billion of divestments as part of Shell’s drive for
on-going capital efficiency and portfolio improvement.”
FOURTH QUARTER 2011 PORTFOLIO DEVELOPMENTS
Upstream
In Australia, a final investment decision was taken on the Greater Western Flank Phase
1 project (Shell share 20.6%). The project is expected to produce some 110 thousand
barrels of oil equivalent per day (“boe/d”) at peak production and represents the next
major development for the North West Shelf Project.
Also in Australia, shareholders of Bow Energy Ltd. approved its acquisition by Arrow
Energy Holdings Pty Ltd. (“Arrow”), a joint venture (Shell share 50%) between Shell and
PetroChina. Shell’s share of the funding for this acquisition by Arrow is some $0.3
billion. The acquisition was completed in January 2012.
In Brazil, Shell completed the sale of its 20% interest in the offshore oil and gas
exploration block BM-S-8 in the Santos Basin for a consideration of some $0.4 billion.
In Cameroon, Shell sold its 80% interest in Pecten Cameroon Company LLC (Shell share
of production of 10 thousand boe/d) for a consideration of some $0.5 billion.
In Indonesia, Shell entered into the Masela production-sharing contract (“PSC”) with a
30% stake for a consideration of some $0.9 billion. The Masela PSC contains the Abadi gas
discovery, which is planned to commence front-end engineering and design for a Floating
LNG project in 2012, initially for 2.5 million tonnes per annum (“mtpa”) capacity, with
the potential for significant project expansions at a later stage.
In Iraq, final government approvals were received to form the Basrah Gas Company, a
joint venture between Iraq’s South Gas Company (51%), Shell (44%) and Mitsubishi
Corporation (5%). The Basrah Gas Company will ultimately gather and process some 2 billion
cubic feet per day (“bcf/d”) of raw gas from the Rumaila, Zubair and West Qurna 1 fields,
initially supplying domestic markets with a longer-term option to develop LNG export
capacity.
In Korea, Shell signed a binding Heads of Agreement for the long-term supply of 3.64
mtpa of LNG to Kogas for twenty years from 2016 and 1 mtpa of LNG from 2013 to 2016.
This supply agreement brings the total LNG sales contracts in Shell’s global LNG
portfolio signed during 2011 to some 6 mtpa. These long-term contracts are linked to oil
prices and at today’s oil prices these would be valued at around $100 billion.
In Malaysia, Shell extended two PSCs by 30 years for enhanced oil recovery projects
offshore Sarawak and Sabah. The improvement in recovery efficiency of the Baram Delta
(Shell share 40%) and North Sabah (Shell share 50%) oil fields is expected to result in
additional oil production and extend field life to beyond 2040.
In Nigeria, Shell sold its 30% interest in Oil Mining Leases 26 and 42 and related
facilities in the Niger Delta (Shell share of production of 6 thousand boe/d) for a
consideration of some $0.5 billion.
In Norway, Shell completed the sale of its interests in the natural gas transport
infrastructure joint venture Gassled for a consideration of some $0.7 billion, with
proceeds received in January 2012.
During the fourth quarter 2011, Shell participated in the Vos-1 (Shell share 50%) and
the Satyr-3 (Shell share 25%) gas discoveries, both in the Carnarvon Basin offshore
Australia, and had a substantial new oil discovery near the Clair field in the UK. Shell
also continued with appraisal successes in our global tight gas portfolio in Australia,
China and in North America in the Groundbirch, Marcellus, and liquids-rich Eagle Ford
plays.
As part of our global exploration programme, Shell spent some $0.7 billion on new
acreage positions during the quarter. New positions include offshore Australia, the
Russian Arctic onshore, offshore and onshore Turkey and additions to existing liquids-rich
shale positions in Canada, Colombia and the USA.
Also, Shell’s application for its working interest in the French Guiana deepwater
block was approved by the French government and Shell assumed operatorship on February 1,
2012. Shell increased its working interest in this acreage from 33% to 45%.
Downstream
In Germany, Shell agreed to transfer the operations of the base oil production at
Harburg refinery to a third party. The remaining facilities of the 108 thousand barrels
per day (“b/d”) refinery (Shell share 100%) will be converted into an oil products
terminal by 2013.
In the United Kingdom, Shell completed the acquisition of 253 retail stations from the
Snax 24 Consortium Partnership for a consideration of some $0.4 billion.
Shell completed the sale of the majority of its shareholding of its downstream
businesses in Cape Verde, Madagascar, Mali, Mauritius, Morocco, Senegal and Tunisia. This
represents the first stage of the divestment of the majority of Shell’s shareholding in
most of its downstream businesses in Africa as announced in February 2011, with the
remainder expected to be completed in 2012.
In Qatar, Shell and Qatar Petroleum signed a Heads of Agreement for the development of
a world-scale petrochemicals complex (Shell share 20%). The scope under consideration
includes a plant of up to 1.5 mtpa mono-ethylene glycol and 0.3 mtpa of linear alpha
olefins.
Key features of the fourth quarter and full year 2011
- Fourth quarter 2011 CCS earnings (see Note 1) were $6,459 million, 13%
higher than in the same quarter a year ago. Full year 2011 CCS earnings were $28,625
million, 54% higher than in 2010.
- Fourth quarter 2011 CCS earnings excluding identified items (see page 5) were
$4,846 million, compared with $4,110 million in the fourth quarter 2010. Full year
2011 CCS earnings excluding identified items were $24,687 million, compared with
$18,073 million in 2010.
- Basic CCS earnings per share increased by 12% versus the same quarter a year
ago. Full year 2011 basic CCS earnings per share increased by 52% compared with 2010.
- Basic CCS earnings per share excluding identified items increased by 16%
versus the same quarter a year ago. Full year 2011 basic CCS earnings per share
excluding identified items increased by 35% compared with 2010.
- Cash flow from operating activities for the fourth quarter 2011 was $6.5
billion, compared with $5.5 billion in the same quarter last year. Excluding net
working capital movements, cash flow from operating activities in the fourth quarter
2011 was $7.2 billion, compared with $6.2 billion in the same quarter last year.
Full year 2011 cash flow from operating activities was $36.8 billion, compared
with $27.4 billion in 2010. Excluding net working capital movements, cash flow from
operating activities in 2011 was $43.2 billion, compared with $33.3 billion in 2010.
- Total dividends distributed in the fourth quarter 2011 were $2.6 billion of
which some $0.9 billion were settled by issuing some 27.3 million Class A shares under
the scrip dividend programme for the third quarter 2011. Some 9.1 million Class B
shares, equivalent to $0.3 billion, were bought back for cancellation during the
quarter under our share buyback programme.
Total dividends distributed in the full year 2011 were $10.5 billion of which $3.6
billion were settled by issuing some 104.6 million Class A shares under the scrip
dividend programme. Some 34.4 million Class B shares, equivalent to $1.1 billion, were
bought back for cancellation.
- Net capital investment (see Note 1) for the fourth quarter 2011 was $9.7
billion, bringing the full year 2011 total to $23.5 billion. Capital investment was
$11.0 billion for the fourth quarter 2011 and $31.1 billion for the full year 2011.
- Return on average capital employed (ROACE) (see Note 3) for 2011 on a reported
income basis was 15.9%.
- Gearing was 13.1% at the end of 2011 versus 17.1% at the end of 2010.
- When final volumes are reported in the 2011 Annual Report / Form 20-F, Shell
expects that proved oil and gas reserves additions before taking into account
production on an SEC basis will be around 1.2 billion boe.
With 2011 production of some 1.2 billion boe, our headline proved Reserves
Replacement Ratio for the year on an SEC basis is expected to be around 100%. Our
Organic Reserves Replacement Ratio, which excludes the impact of oil price movements
in the year, acquisitions and divestments, is expected to be around 120%.
At the end of 2011, total proved reserves on an SEC basis are expected to be
around 14.2 billion to 14.3 billion boe, in line with the end of 2010, after taking
into account 2011 production. As a consequence, Shell's reserves to production ratio
is expected to remain around 12 years at the end of 2011, in line with the end of
2010.
The 3 year average headline proved Reserves Replacement Ratio on an SEC basis is
expected to be around 160%. Further information will be provided in our Annual Report
/ Form 20-F, which is expected to be filed in March 2012.
- Supplementary financial and operational disclosure for the fourth quarter and
full year 2011 is available at http://www.shell.com/investor.
Summary of identified items
CCS earnings in the fourth quarter 2011 reflected the following items, which in
aggregate amounted to a net gain of $1,613 million (compared with a net gain of $1,586
million in the fourth quarter 2010), as summarised in the table below:
- Upstream earnings included a net gain of $1,458 million, mainly reflecting
divestment gains, the estimated fair value accounting for commodity derivatives (see
Note 2) and the mark-to-market valuation of certain gas contracts. Earnings for the
fourth quarter 2010 included a net gain of $1,657 million.
- Downstream earnings included a net gain of $34 million, mainly reflecting a
tax credit and a net divestment gain, partly offset by a provision. Earnings for the
fourth quarter 2010 included a net charge of $71 million.
- Corporate and Non-controlling interest earnings included a net gain of $121
million, mainly reflecting a divestment gain.
Summary of identified items
Quarters $ million Full year
Q4 2011 Q3 2011 Q4 2010 2011 2010
Identified items:
1,458 636 1,657 Upstream 3,855 1,493
34 (338) (71) Downstream 15 (923)
Corporate and Non-controlling
121 (53) - interest 68 -
1,613 245 1,586 CCS earnings impact 3,938 570
These identified items generally relate to events with an impact of more than $50
million on Royal Dutch Shell’s CCS earnings and are shown to provide additional insight
into segment earnings and income attributable to shareholders. Further comments on the
business segments are provided in the section ‘Earnings by Business Segment’ on pages 6 to
8.
EARNINGS BY BUSINESS SEGMENT
UPSTREAM
Quarters $ million Full year
Q4 2011 Q3 2011 Q4 2010 %[1] 2011 2010 %
Upstream earnings excluding
5,107 5,435 3,440 +48 identified items 20,600 14,442 +43
6,565 6,071 5,097 +29 Upstream earnings 24,455 15,935 +53
Upstream cash flow from
6,485 8,520 5,596 +16 operating activities 30,579 24,872 +23
Upstream net capital
7,363 5,944 522 - investment 19,083 21,222 -10
Liquids production
available for sale
1,644 1,676 1,741 -6 (thousand b/d) 1,666 1,709 -3
Natural gas production
available for sale (million
9,633 7,749 10,184 -5 scf/d) 8,986 9,305 -3
Barrels of oil equivalent
3,305 3,012 3,496 -5 (thousand boe/d) 3,215 3,314 -3
LNG sales volumes (million
4.84 4.76 4.39 +10 tonnes) 18.83 16.76 +12
[1] Q4 on Q4 change
Fourth quarter Upstream earnings excluding identified items were $5,107 million
compared with $3,440 million a year ago. Identified items were a net gain of $1,458
million, compared with a net gain of $1,657 million in the fourth quarter 2010 (see page
5).
Upstream earnings excluding identified items increased compared with the fourth
quarter 2010. Earnings reflected higher liquids and natural gas realisations. Earnings
also reflected higher LNG realisations, increased LNG sales volumes and higher dividends
from an LNG venture. These items were partly offset by lower liquids and natural gas
production volumes, higher depreciation and increased exploration expense.
Global liquids realisations were 30% higher than in the fourth quarter 2010. Global
natural gas realisations were 12% higher than in the same quarter a year ago. While
natural gas realisations in the Americas decreased by 10%, natural gas realisations
outside the Americas increased by 22%.
Fourth quarter 2011 production was 3,305 thousand boe/d compared with 3,496 thousand
boe/d a year ago. Excluding the impact of divestments of some 90 thousand boe/d, fourth
quarter 2011 production was 3% lower than in the same period last year.
New field start-ups and the continuing ramp-up of fields contributed some 290 thousand
boe/d to production in the fourth quarter 2011, in particular from Pearl GTL and Qatargas
4 LNG in Qatar, which more than offset the impact of field declines.
LNG sales volumes of 4.84 million tonnes were 10% higher than in the same quarter a
year ago, reflecting the contribution of Qatargas 4 LNG.
Full year Upstream earnings excluding identified items were $20,600 million compared
with $14,442 million in 2010. Identified items were a net gain of $3,855 million, mainly
reflecting divestment gains, compared with a net gain of $1,493 million in 2010.
Upstream earnings excluding identified items increased compared with 2010, reflecting
higher liquids and natural gas realisations and increased trading contributions. Earnings
also reflected higher LNG sales volumes and higher realised LNG prices as well as
increased dividends from an LNG venture. These items were offset by higher operating
expenses, mainly reflecting the start-up of new projects, lower liquids and natural gas
production volumes and increased taxes.
Global liquids realisations were 39% higher than in 2010. Global natural gas
realisations were 18% higher than in 2010. Natural gas realisations in the Americas
decreased by 8%, whereas natural gas realisations outside the Americas increased by 26%.
Full year 2011 production was 3,215 thousand boe/d compared with 3,314 thousand boe/d
for 2010. Excluding the impact of divestments of some 100 thousand boe/d, full year 2011
production was in line with 2010.
New field start-ups and the continuing ramp-up of fields contributed some 270 thousand
boe/d to production in the full year 2011, in particular from Pearl GTL and Qatargas 4 LNG
in Qatar as well as Gbaran Ubie in Nigeria and AOSP Expansion 1 in Canada, which more than
offset the impact of field declines.
LNG sales volumes of 18.83 million tonnes were 12% higher than in 2010, reflecting the
successful ramp-up of Qatargas 4 LNG during the year as well as higher volumes from
Nigeria LNG and the Sakhalin II project.
DOWNSTREAM
Quarters $ million Full year
Q4 2011 Q3 2011 Q4 2010 %[1] 2011 2010 %
Downstream CCS earnings
(278) 1,818 482 - excluding identified items 4,274 3,873 +10
(244) 1,480 411 - Downstream CCS earnings 4,289 2,950 +45
Downstream cash flow from
324 2,069 (348) - operating activities 4,921 1,961 +151
Downstream net capital
2,362 149 991 +138 investment 4,342 2,358 +84
Refinery processing intake
2,666 2,854 3,201 -17 (thousand boe/d) 2,845 3,197 -11
Oil products sales volumes
6,155 6,374 6,670 -8 (thousand b/d) 6,196 6,460 -4
Chemicals sales volumes
4,440 4,832 5,297 -16 (thousand tonnes) 18,831 20,653 -9
[1] Q4 on Q4 change
Fourth quarter Downstream earnings excluding identified items were a loss of $278
million compared with a profit of $482 million in the fourth quarter 2010. Identified
items were a net gain of $34 million, compared with a net charge of $71 million in the
fourth quarter 2010 (see page 5).
Downstream results excluding identified items decreased compared with the fourth
quarter 2010. Earnings reflected lower operating expenses and improved oil products unit
marketing margins. These items were more than offset by lower realised refining margins,
reflecting the deterioration in the global refining environment. Compared to the same
quarter last year, Downstream results were also impacted by lower oil products and
chemicals sales volumes as well as reduced trading contributions.
Oil products sales volumes decreased by 8% compared with the same period a year ago as
a result of portfolio divestments and weakening global demand. Excluding the impact of
divestments and the effects of the formation of the Raizen joint venture, a total of some
260 thousand b/d, sales volumes were 4% lower than in the same period last year.
Chemicals sales volumes decreased by 16% compared with the same quarter last year, due
to lower plant availability and the impact of weakening global demand. Chemicals
manufacturing plant availability decreased to 86% compared with 94% in the fourth quarter
2010, as a result of increased maintenance activities.
Refinery intake volumes decreased by 17% compared with the fourth quarter of 2010,
mainly as a result of portfolio divestments. Excluding portfolio impacts, refinery intake
volumes were 9% lower than in the same period a year ago. Refinery availability of 92% was
in line with the fourth quarter 2010.
Full year Downstream earnings excluding identified items were $4,274 million compared
with $3,873 million in 2010. Identified items were a net gain of $15 million, compared
with a net charge of $923 million in 2010.
Downstream earnings excluding identified items increased compared with 2010. Earnings
reflected higher contributions from trading, lower operating expenses and higher chemicals
unit margins, due to favourable market conditions during most of the year. These items
were partly offset by lower realised refining margins, as a result of the weaker global
refining environment. Compared to the previous year, Downstream earnings were also
impacted by lower oil products and chemicals sales volumes.
Oil products sales volumes decreased by 4% compared with 2010, as a result of
portfolio divestments and weakening demand. Excluding both the impact of divestments and
the effects of the formation of the Raizen joint venture, a total of some 210 thousand
b/d, sales volumes decreased by 1% compared with 2010.
Chemicals sales volumes decreased by 9% compared with 2010, mainly due to lower plant
availability. Chemicals manufacturing plant availability decreased to 89% compared with
92% in 2010, as a result of increased maintenance activities.
Refinery intake volumes decreased by 11% compared with 2010, mainly as a result of
portfolio divestments and refinery closures. Excluding portfolio impacts, refinery intake
volumes were 2% lower compared with 2010. Refinery availability of 92% was in line with
2010.
Corporate and Non-controlling Interest
Quarters $ million Full year
Q4 2011 Q3 2011 Q4 2010 2011 2010
Corporate and Non-controlling interest
17 (252) 188 excl. identified items (187) (242)
Of which:
24 (201) 231 Corporate 63 91
(7) (51) (43) Non-controlling interest (250) (333)
138 (305) 188 Corporate and Non-controlling interest (119) (242)
Fourth quarter Corporate results and Non-controlling interest excluding identified
items were a gain of $17 [CQ_US_CORPCLEAN ] million compared with a gain of $188 million
in the same period last year. Identified items in the fourth quarter 2011 were a net gain
of $121 million (see page 5).
Corporate earnings excluding identified items were lower compared with the fourth
quarter 2010, mainly reflecting unfavourable currency exchange rate effects of $25 million
compared with favourable currency exchange rate effects of $215 million in the fourth
quarter 2010. Results also reflected higher net interest expense and higher costs. These
items were partly offset by increased tax credits.
Full year Corporate results and Non-controlling interest excluding identified items
were a loss of $187 million compared with a loss of $242 million in 2010. Identified items
in the full year 2011 were a net gain of $68 million.
Corporate earnings excluding identified items were lower compared with 2010,
reflecting higher net interest expense and unfavourable currency exchange rate effects,
largely offset by increased tax credits and lower costs.
FORTHCOMING EVENTS
First quarter 2012 results and first quarter 2012 dividend are scheduled to be
announced on April 26, 2012. Second quarter 2012 results and second quarter 2012 dividend
are scheduled to be announced on July 26, 2012. Third quarter 2012 results and third
quarter 2012 dividend are scheduled to be announced on November 1, 2012.
Unaudited Condensed Consolidated Financial Statements
Consolidated Statement of Income
Quarters $ million Full year
Q4 2011 Q3 2011 Q4 2010 %[1] 2011 2010 %
115,575 123,412 100,714 Revenue 470,171 368,056
Share of profit of
equity-accounted
2,233 2,041 1,979 investments 8,737 5,953
1,320 504 2,832 Interest and other income 5,581 4,143
Total revenue and other
119,128 125,957 105,525 income 484,489 378,152
91,865 98,094 78,138 Purchases 370,044 283,176
Production and
6,993 6,761 7,294 manufacturing expenses 26,458 24,458
Selling, distribution and
3,706 3,516 4,301 administrative expenses 14,335 15,528
404 253 422 Research and development 1,125 1,019
825 661 646 Exploration 2,266 2,036
Depreciation, depletion
3,243 3,803 3,236 and amortisation 13,228 15,595
287 331 227 Interest expense 1,373 996
11,805 12,538 11,261 +5 Income before taxation 55,660 35,344 +57
5,337 5,505 4,405 Taxation 24,475 14,870
6,468 7,033 6,856 -6 Income for the period 31,185 20,474 +52
Income attributable to
(32) 57 66 non-controlling interest 267 347
Income attributable to
Royal Dutch Shell plc
6,500 6,976 6,790 -4 shareholders 30,918 20,127 +54
Current cost of supplies
(CCS) adjustment for
(41) 270 (1,094) Downstream (2,293) (1,484)
6,459 7,246 5,696 +13 CCS earnings 28,625 18,643 +54
1,613 245 1,586 Less: Identified items 3,938 570
CCS earnings excluding
4,846 7,001 4,110 +18 identified items 24,687 18,073 +37
Basic earnings per share
Quarters Full year
Q4 2011 Q3 2011 Q4 2010 $ 2011 2010
1.04 1.12 1.11 Earnings per share 4.98 3.28
1.04 1.16 0.93 CCS earnings per share 4.61 3.04
CCS earnings per share excl.
0.78 1.12 0.67 identified items 3.97 2.95
Diluted earnings per share
Quarters Full year
Q4 2011 Q3 2011 Q4 2010 $ 2011 2010
1.04 1.12 1.10 Earnings per share 4.97 3.28
1.03 1.16 0.93 CCS earnings per share 4.60 3.04
CCS earnings per share excl.
0.78 1.12 0.67 identified items 3.97 2.94
Shares[2]
Quarters Millions Full year
Q4 2011 Q3 2011 Q4 2010 2011 2010
Weighted average number of shares
as the basis for:
6,231.3 6,238.1 6,137.3 Basic earnings per share 6,212.5 6,132.6
6,241.0 6,247.1 6,147.4 Diluted earnings per share 6,221.7 6,139.3
Shares outstanding at the end of
6,220.1 6,236.5 6,154.2 the period 6,220.1 6,154.2
[1] Q4 on Q4 change.
[2] Royal Dutch Shell plc ordinary shares of EUR0.07 each.
Consolidated Statement of Comprehensive Income
Quarters $ million Full year
Q4 2011 Q3 2011 Q4 2010 2011 2010
6,468 7,033 6,856 Income for the period 31,185 20,474
Other comprehensive income, net of
tax:
(1,310) (4,642) (24) Currency translation differences (3,328) (142)
Unrealised gains/(losses) on
1,671 23 (182) securities 1,684 (298)
(133) (130) (16) Cash flow hedging gains/(losses) (222) (2)
Share of other comprehensive
income/(loss) of equity-accounted
(39) 29 482 investments 60 488
Other comprehensive income/(loss)
189 (4,720) 260 for the period (1,806) 46
6,657 2,313 7,116 Comprehensive income for the period 29,379 20,520
Comprehensive income/(loss)
attributable to non-controlling
(603) (46) 51 interest (348) 389
Comprehensive income attributable
to Royal Dutch Shell plc
7,260 2,359 7,065 shareholders 29,727 20,131
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
Equity attributable to Royal Dutch
Shell plc shareholders
Ordinary
share Shares
capital held in Other Retained Non-controlling Total
$ million trust reserves earnings Total interest equity
At January 1,
2011 529 (2,789) 10,094 140,179 148,013 1,767 149,780
Comprehensive
income for the
period - - (1,191) 30,918 29,727 (348) 29,379
Capital
contributions
from and other
changes in
non-controlling
interest - - - 41 41 505 546
Dividends paid - - - (10,457) (10,457) (438) (10,895)
Scrip
dividends[1] 10 - (10) 3,580 3,580 - 3,580
Repurchases of
shares (3) - 3 (1,106) (1,106) - (1,106)
Shares held in
trust: net
sales/
(purchases) and
dividends
received - (201) - 142 (59) - (59)
Share-based
compensation - - 88 (310) (222) - (222)
At December 31,
2011 536 (2,990) 8,984 162,987 169,517 1,486 171,003
[1] During 2011 some 104.6 million Class A shares, equivalent to $3.6
billion, were issued under the Scrip Dividend Programme.
Equity attributable to Royal Dutch
Shell plc shareholders
Ordinary
share Shares
capital held in Other Retained Non-controlling Total
$ million trust reserves earnings Total interest equity
At January 1,
2010 527 (1,711) 9,982 127,633 136,431 1,704 138,135
Comprehensive
income for the
period - - 4 20,127 20,131 389 20,520
Capital
contributions
from and other
changes in
non-controlling
interest - - - 283 283 69 352
Dividends paid - - - (10,196) (10,196) (395) (10,591)
Scrip
dividends[2] 2 - (2) 612 612 - 612
Shares held in
trust: net
sales/
(purchases) and
dividends
received - (1,078) - 1,521 443 - 443
Share-based
compensation - - 110 199 309 - 309
At December 31,
2010 529 (2,789) 10,094 140,179 148,013 1,767 149,780
[2] During 2010 some 18.3 million Class A shares, equivalent to $0.6 billion,
were issued under the Scrip Dividend Programme.
CONDENSED CONSOLIDATED BALANCE SHEEET
$ million
Sept 30,
Dec 31, 2011 2011 Dec 31, 2010
Assets
Non-current assets:
Intangible assets 4,521 4,500 5,039
Property, plant and equipment 152,081 147,027 142,705
Equity-accounted investments 37,990 38,321 33,414
Investments in securities 5,492 3,915 3,809
Deferred tax 4,732 5,512 5,361
Prepaid pension costs 11,408 11,132 10,368
Trade and other receivables 9,256 9,040 8,970
225,480 219,447 209,666
Current assets:
Inventories 28,976 30,250 29,348
Trade and other receivables 79,509 78,529 70,102
Cash and cash equivalents 11,292 19,256 13,444
119,777 128,035 112,894
Total assets 345,257 347,482 322,560
Liabilities
Non-current liabilities:
Debt 30,463 31,092 34,381
Trade and other payables 4,921 5,415 4,250
Deferred tax 14,649 15,814 13,388
Retirement benefit obligations 5,931 5,988 5,924
Decommissioning and other
provisions 15,631 15,442 14,285
71,595 73,751 72,228
Current liabilities:
Debt 6,712 8,268 9,951
Trade and other payables 81,846 80,357 76,550
Taxes payable 10,606 15,305 10,306
Retirement benefit obligations 387 374 377
Decommissioning and other
provisions 3,108 3,224 3,368
102,659 107,528 100,552
Total liabilities 174,254 181,279 172,780
Equity attributable to Royal Dutch
Shell plc shareholders 169,517 164,601 148,013
Non-controlling interest 1,486 1,602 1,767
Total equity 171,003 166,203 149,780
Total liabilities and equity 345,257 347,482 322,560
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
Quarters $ million Full year
Q4 2011 Q3 2011 Q4 2010 2011 2010
Cash flow from operating
activities:
6,468 7,033 6,856 Income for the period 31,185 20,474
Adjustment for:
5,816 5,746 4,515 - Current taxation 23,009 16,384
275 249 186 - Interest expense (net) 1,164 842
- Depreciation, depletion and
3,243 3,803 3,236 amortisation 13,228 15,595
- Net (gains)/losses on sale of
(1,150) (347) (2,344) assets (4,485) (3,276)
- Decrease/(increase) in net
(688) 1,011 (754) working capital (6,471) (5,929)
- Share of profit of
(2,233) (2,041) (1,979) equity-accounted investments (8,737) (5,953)
- Dividends received from
equity-accounted
3,196 2,402 2,064 investments 9,681 6,519
- Deferred taxation and other
(159) (204) (468) provisions 1,768 (1,934)
(550) (540) (696) - Other (949) (10)
Net cash from operating
14,218 17,112 10,616 activities (pre-tax) 59,393 42,712
(7,753) (5,467) (5,160) Taxation paid (22,622) (15,362)
Net cash from operating
6,465 11,645 5,456 activities 36,771 27,350
Cash flow from investing
activities:
(9,914) (7,261) (5,571) Capital expenditure (26,301) (26,940)
Investments in equity-accounted
(315) (199) (110) investments (1,886) (2,050)
1,175 1,594 1,286 Proceeds from sale of assets 6,990 3,325
Proceeds from sale of
43 200 3,380 equity-accounted investments 468 3,591
(Additions to)/proceeds from
83 6 (16) sale of securities 90 (34)
11 75 34 Interest received 196 136
Net cash used in investing
(8,917) (5,585) (997) activities (20,443) (21,972)
Cash flow from
financing activities:
Net (decrease)/increase in debt
with maturity period
(841) (365) 248 within three months (3,724) 4,647
5 477 120 Other debt: New borrowings 1,249 7,849
(585) (2,529) (388) Repayments (4,649) (3,240)
(470) (173) (108) Interest paid (1,665) (1,312)
Change in non-controlling
11 (3) 66 interest 8 381
Dividends paid to:
- Royal Dutch Shell plc
(1,688) (1,865) (1,998) shareholders (6,877) (9,584)
(64) (175) (38) - Non-controlling interest (438) (395)
(289) (817) - Repurchases of shares (1,106) -
Shares held in trust: net
sales/(purchases) and dividends
(1,342) 10 17 received (929) 187
Net cash from/(used in)
(5,263) (5,440) (2,081) financing activities (18,131) (1,467)
Currency translation
differences relating to cash
and
(249) (829) (216) cash equivalents (349) (186)
(Decrease)/increase in cash and
(7,964) (209) 2,162 cash equivalents (2,152) 3,725
Cash and cash equivalents at
19,256 19,465 11,282 beginning of period 13,444 9,719
Cash and cash equivalents at
11,292 19,256 13,444 end of period 11,292 13,444
EXPLANATORY NOTES
1. Basis of preparation
The unaudited quarterly and full year financial report and tables of Royal Dutch Shell
plc and its subsidiaries (collectively known as “Shell”) are prepared on the basis of the
same accounting principles as, and should be read in conjunction with, the Annual Report /
Form 20-F for the year ended December 31, 2010 (pages 102 to 107) as filed with the US
Securities and Exchange Commission.
The information for the periods ended December 31, 2011 does not comprise statutory
accounts for the purposes of section 435 of the Companies Act 2006. Statutory accounts for
the year ended December 31, 2010 were approved by the Board of Directors and delivered to
the Registrar of Companies. The report of the auditors on those accounts was unqualified,
did not include a reference to any matters to which the auditors drew attention by way of
emphasis without qualifying the report, and did not contain any statement under sections
498(2) or (3) of the Companies Act 2006.
Segment information
Segment earnings are presented on a current cost of supplies basis (CCS earnings). On
this basis, the purchase price of volumes sold during the period is based on the estimated
current cost of supplies during the same period after making allowance for the estimated
tax effect. CCS earnings thus exclude the effect of changes in the oil price on inventory
carrying amounts. Net capital investment information is presented as measured based on
capital expenditure as reported in the Condensed Consolidated Statement of Cash Flows,
adjusted for: proceeds from divestments; exploration expenses excluding exploration wells
written off; investments in equity-accounted investments; leases and other items.
CCS earnings and net capital investment information are the dominant measures used by
the Chief Executive Officer for the purposes of making decisions about allocating
resources and assessing performance.
2. Impacts of accounting for derivatives
In the ordinary course of business Shell enters into contracts to supply or purchase
oil and gas products, and also enters into derivative contracts to mitigate resulting
economic exposures (generally price exposure). Derivative contracts are carried at
period-end market price (fair value), with movements in fair value recognised in income
for the period. Supply and purchase contracts entered into for operational purposes are,
by contrast, recognised when the transaction occurs (see also below); furthermore,
inventory is carried at historical cost or net realisable value, whichever is lower.
As a consequence, accounting mismatches occur because: (a) the supply or purchase
transaction is recognised in a different period; or (b) the inventory is measured on a
different basis.
In addition, certain UK gas contracts held by the Upstream business are, due to
pricing or delivery conditions, deemed to contain embedded derivatives or written options
and are also required to be carried at fair value even though they are entered into for
operational purposes.
The accounting impacts of the aforementioned are reported as identified items in the
quarterly results.
3. Return on average capital employed (ROACE)
ROACE measures the efficiency of Shell’s utilisation of the capital that it employs.
In this calculation, ROACE is defined as the sum of income for the year adjusted for
after-tax interest expense as a percentage of the average capital employed for the same
period. Capital employed consists of total equity, current debt and non-current debt.
CAUTIONARY STATEMENT
All amounts shown throughout this report are unaudited.
The companies in which Royal Dutch Shell plc directly and indirectly owns investments
are separate entities. In this report “Shell”, “Shell group” and “Royal Dutch Shell” are
sometimes used for convenience where references are made to Royal Dutch Shell plc and its
subsidiaries in general. Likewise, the words “we”, “us” and “our” are also used to refer
to subsidiaries in general or to those who work for them. These expressions are also used
where no useful purpose is served by identifying the particular company or companies.
“Subsidiaries”, “Shell subsidiaries” and “Shell companies” as used in this report refer to
companies in which Royal Dutch Shell either directly or indirectly has control, by having
either a majority of the voting rights or the right to exercise a controlling influence.
The companies in which Shell has significant influence but not control are referred to as
“associated companies” or “associates” and companies in which Shell has joint control are
referred to as “jointly controlled entities”. In this report, associates and jointly
controlled entities are also referred to as “equity-accounted investments”. The term
“Shell interest” is used for convenience to indicate the direct and/or indirect ownership
interest held by Shell in a venture, partnership or company, after exclusion of all
third-party interest. (For example, Shell interest in Woodside Petroleum Ltd is 24%.)
This report contains forward-looking statements concerning the financial condition,
results of operations and businesses of Royal Dutch Shell. All statements other than
statements of historical fact are, or may be deemed to be, forward-looking statements.
Forward-looking statements are statements of future expectations that are based on
management’s current expectations and assumptions and involve known and unknown risks and
uncertainties that could cause actual results, performance or events to differ materially
from those expressed or implied in these statements. Forward-looking statements include,
among other things, statements concerning the potential exposure of Royal Dutch Shell to
market risks and statements expressing management’s expectations, beliefs, estimates,
forecasts, projections and assumptions. These forward-looking statements are identified by
their use of terms and phrases such as “anticipate”, “believe”, “could”, “estimate”,
“expect”, “goals”, “intend”, “may”, “objectives”, “outlook”, “plan”, “probably”,
“project”, “risks”, “scheduled”, “seek”, “should”, “target”, “will” and similar terms and
phrases. There are a number of factors that could affect the future operations of Royal
Dutch Shell and could cause those results to differ materially from those expressed in the
forward-looking statements included in this report, including (without limitation): (a)
price fluctuations in crude oil and natural gas; (b) changes in demand for Shell’s
products; (c) currency fluctuations; (d) drilling and production results; (e) reserves
estimates; (f) loss of market share and industry competition; (g) environmental and
physical risks; (h) risks associated with the identification of suitable potential
acquisition properties and targets, and successful negotiation and completion of such
transactions; (i) the risk of doing business in developing countries and countries subject
to international sanctions; (j) legislative, fiscal and regulatory developments including
regulatory measures addressing climate change; (k) economic and financial market
conditions in various countries and regions; (l) political risks, including the risks of
expropriation and renegotiation of the terms of contracts with governmental entities,
delays or advancements in the approval of projects and delays in the reimbursement for
shared costs; and (m) changes in trading conditions. All forward-looking statements
contained in this report are expressly qualified in their entirety by the cautionary
statements contained or referred to in this section. Readers should not place undue
reliance on forward-looking statements. Additional factors that may affect future results
are contained in Royal Dutch Shell’s Annual Report / Form 20-F for the year ended December
31, 2010 (available at http://www.shell.com/investor and http://www.sec.gov).
These factors also should be considered by the reader. Each forward-looking statement
speaks only as of the date of this report, February 2, 2012. Neither Royal Dutch Shell nor
any of its subsidiaries undertake any obligation to publicly update or revise any
forward-looking statement as a result of new information, future events or other
information. In light of these risks, results could differ materially from those stated,
implied or inferred from the forward-looking statements contained in this report.
February 2, 2012
Contacts:
Investor Relations: Europe: +31(0)70-377-4540; USA: +1-713-241-1042
Media: Europe: +31(0)70-377-3600; USA +1-713-241-4544
SOURCE Royal Dutch Shell plc
