Bg Data Book 07

Portfolio for growth

BG Group Data Book 2007

STATISTICAL SUPPLEMENT

COUNTRIES A-Z

Alaska Algeria Argentina Bolivia Brazil Canada Chile China Egypt Europe Downstream India Israel and areas of Palestinian Authority Italy Kazakhstan

32 29 14 15 17 32 16 21 25 4 19 28 11 12

Libya Madagascar Malaysia Nigeria Norway Oman Philippines Singapore Thailand Trinidad and Tobago Tunisia UK Upstream United States of America Uruguay

29 29 21 30 10 24 22 21 23 33 31 6 36 16

Introduction and Legal Notices Social and Environment Data Group Financial Data Exploration and Production (E&P) Liquefied Natural Gas (LNG) Transmission and Distribution (T&D) Power Corporate Information Definitions

40 41 42 45 50 51 51 52 54

OPERATIONAL AND FINANCIAL GUIDANCE TABLE Timescale 2007

E&P

Production growth

LNG

Contracted supply

2006-2009

2009

5-7%

2005-2012

6-10%

21-24%

Liquefaction capital invested

16-20%

£0.9 bn

Liquefaction return on capital invested

ca.13%

Shipping and marketing volumes Shipping and marketing EBITDA margin T&D

2005-2009

Comgas volume growth

12.3 mtpa

13.5 mtpa

16%

18%

7-8%

Share buy-back

£750 m

Dividend Policy

Dividend growth in line with underlying earnings growth

Guidance as at February 2007. For an analysis of the factors that may affect BG Group’s actual results, please refer to the Risk Factors in the BG Group Annual Report and Accounts 2006.

COVER IMAGE – EXPLORATION AND PRODUCTION RESERVES AND RESOURCES BASE

CAGR 10% 2004-2006

2006 RESERVES/PRODUCTION*

7 000

7 071

8 000

6 595

9 000

8 017

(mmboe)

37 years

6 000

Long-term reserves The cover image represents BG Group’s reserves and resource base, which grew by almost 1 billion barrels of oil equivalent during 2006, an increase of around 13%. This resource base can deliver 37 years of production at 2006 rates.

5 000 24 years

4 000 3 000

16 years

2 000 10 years

1 000 0 04

05

06

Risked Exploration Un-booked Resources Probable Reserves SEC Proved Reserves *Based on 2006 production of 219.2 mmboe

1

Our vision

Natural gas is our business. We are a rapidly growing company, with expertise across the gas chain. Our vision is to be the leading natural gas company in the global energy market – operating responsibly and delivering outstanding value to our shareholders. A decade of outstanding growth E&P PRODUCTION VOLUMES

7

504

1

100

97 98 99 00 01 02 03 04 05 06

4.1 1.1

2

0

0

0

2.8

3

3.2

457

4

0.8

200

280

300

240

238

400

6 5

298

373

500

428

600

6.7

700

601(d)

(mtpa)

0.4

888

330

229

500

160

1 000

833

688

1 500

1 520(c)

1 279

2 000

(’000 boed )

165

3 103 2 389(c)

3 500

2 500

CAGR 50% 1999-2006

CAGR 15% 1997-2006

CAGR 39% 1997-2006 (£m)

3 000

LNG LIQUEFACTION VOLUMES

0.7

TOTAL OPERATING PROFIT(a)(b)

97 98 99 00 01 02 03 04 05 06

97 98 99 00 01 02 03 04 05 06

E&P T&D, LNG, Power and Other

BG GROUP – OIL AND GAS PRODUCTION 2006 Total oil and gas production %

Egypt

28

UK

25

Kazakhstan

17

Trinidad and Tobago

10

Tunisia

6

India

5

Thailand

4

Bolivia

2

Canada

2

Total

100

BG Group Data Book 2007

Group overview

Liquefied Natural Gas

Exploration and Production BG Group explores for, develops, produces and markets gas and oil around the world. Around 76% of 2006 production was gas. The Group uses its technical, commercial and gas chain skills to deliver projects at industry-leading cost levels, whilst maximising the sales value of its hydrocarbons.

BG Group is a producer and marketer of Liquefied Natural Gas (LNG). It has a highly flexible portfolio of LNG and was able to access demand in 12 countries in 2006 and substantially increase profitability by targeting the highest value markets.

MAIN MARKETS AND ACTIVITIES

MAIN MARKETS AND ACTIVITIES

BG Group’s high performing Exploration and Production (E&P) business is the centre of gravity for the Group.

BG Group has the skills and assets to deliver low cost LNG into high value markets around the world.

Production volumes increased by 19.3% in 2006.

• Liquefaction: Egypt; and Trinidad and Tobago

BG Group’s E&P activities achieved top quartile performance in finding and development costs and operating costs compared to its industry peers in 2006.

• Purchased LNG: Egypt; Equatorial Guinea; Nigeria; and Trinidad and Tobago

Production: Bolivia; Canada (most producing assets were sold in April 2007); Egypt; India; Kazakhstan; Mauritania (all assets sold in January 2007); Thailand; Trinidad and Tobago; Tunisia; and UK.

• Regasification: Elba Island (USA); and Lake Charles (USA)

PERFORMANCE HIGHLIGHTS

PERFORMANCE HIGHLIGHTS

Production (’000 boed)

400

9.9

9

601 000 boed

100

3.2

2.8

Total production up 19.3%

200

£352m

4.1

6

300

Total operating profit(a) Business Performance(b)

6.7

£2 457m

6.4

500

12

6.4

457

600

Total operating profit(a) Business Performance(b)

5.7

601(d)

Production and managed volumes (mtpa)

504

700 428

2

3

(d)

0 03

05

04

06

504 000 boed in 2005

03

OUTLOOK

05

06

PROGRESS SECURING NEW LNG SUPPLY

BG Group net production (’000 boed)

BG Group LNG supply (mtpa) CAGR 16-20% 2005-12

CAGR 6-10% 2005-12

1 000

25 CAGR 21-24% 2005-09

CAGR 5-7% 2006-09

800

20

612

15

MEDIUM-TERM 2007-09

400

LONG-TERM 2010-12

10

200

2

0 2005A

04

OUTLOOK

PRODUCTION

600

Production (mtpa) Managed volumes (mtpa)

0

0 2006A

MEDIUM-TERM Key projects: Buzzard Karachaganak Trinidad E&P Panna/Mukta/Tapti Hasdrubal

2009

2012

LONG-TERM Key opportunities: Karachaganak Tupi Abu Butabul Nigeria/Boi Jasmine Jackdaw Bream

Gaza Marine Mukta expansion Bongkot South J Block discoveries Hassi Ba Hamou Margarita Risked exploration

As at February 2007

(a) Including share of pre-tax operating results from joint ventures and associates.

2004A

2005A

2006

Other opportunities Supply subject to SPA* Spot (potential range) Other term supply Long-term firm supply**

2009

*SUPPLY SUBJECT TO SPA NLNG T7 (signed February 2007) Brass LNG OKLNG – equity lifting

**For details refer to page 50

As at February 2007

(b) Business Performance – see page 40 for a description.

(c) Restated under IFRS and for IFRIC 4.

2012

(d) 2006 includes 12 000 boed of fuel gas.

3

1

Europe Downstream UK Upstream Norway Italy Kazakhstan

5

Argentina Bolivia Chile Uruguay Brazil

4 3 2

Power

BG Group has a 4.3 GW(f) portfolio of modern, efficient combined cycle generating turbines.

Transmission and Distribution: Argentina; Brazil; India; and UK.

Power: Italy; Malaysia; Philippines; UK; and USA. Co-generation: Brazil; and India.

PERFORMANCE HIGHLIGHTS

PERFORMANCE HIGHLIGHTS

4.3(f) 2.8

3.0

3

2.8

4 2.8

11.9(e)

13.2

5

13.4

16

12.5

Power capacity (GW)

03

04

05

06

MEDITERRANEAN BASIN AND AFRICA Egypt Israel and areas of Palestinian Authority Algeria Libya Madagascar Nigeria Tunisia

5

NORTH AMERICA AND THE CARIBBEAN AND GLOBAL LNG Canada Alaska Trinidad and Tobago United States of America

8

2 4

NORTH AMERICA AND THE CARIBBEAN

Throughput (bcma)

4

MEDITERRANEAN BASIN AND AFRICA

MAIN MARKETS AND ACTIVITIES

The Group’s T&D businesses are focused on high growth developing markets – principally in Brazil and India.

12

India China Malaysia Philippines Thailand Oman

A large proportion of the worldwide demand for gas is attributable to power generation. BG Group develops, owns and operates gas-fired power generation plants.

MAIN MARKETS AND ACTIVITIES

ASIA PACIFIC

ASIA PACIFIC

3

Transmission and Distribution

SOUTH AMERICA

SOUTH AMERICA

2

BG Group’s Transmission and Distribution (T&D) activities develop markets for natural gas and provide them with supply from its own and others’ production through transmission and distribution networks.

EUROPE AND CENTRAL ASIA

EUROPE AND CENTRAL ASIA

1

1

03

04

05

06

Total operating profit(a) Business Performance(b)

Total operating profit(a) Business Performance(b)

£231m

£106m

(e) Decline due to MetroGAS deconsolidation.

(f) Includes 1.3 GW agreed to acquire in 2006 and early 2007, which has now completed.

STATISTICAL SUPPLEMENT Social and Environment Data Group Financial Data Exploration and Production (E&P) Liquefied Natural Gas (LNG) Transmission and Distribution (T&D) Power Corporate Information Definitions and Conversions

BG Group Data Book 2007

STATISTICAL SUPPLEMENT

0

0

Europe and Central Asia 4

Europe Downstream Key to operations

ABERDEEN

Gas pipeline 0

200km

Premier Power

LARNE

BG Group purchased Premier Power in 1992 and then converted the plant to gas. BG Group also has a 50% stake in the Seabank power station.

TEESSIDE BELFAST

BG Group sells gas on a wholesale basis at beach terminals and ships gas to the UK National Balancing Point. BG Group also exports gas for sale to, and purchases gas for import from, mainland Europe via the Interconnector.

UK IRISH SEA BACTON

Interconnector Dragon LNG, Milford Haven Seabank

READING

BG Group’s Europe Downstream activities encompass power generation, gas transmission and energy marketing. The Group is also jointly developing a LNG import and regasification facility at Milford Haven, Wales.

LONDON

ZEEBRUGGE

PREMIER POWER LIMITED The Ballylumford power station, near Larne, has a potential maximum capacity of 1 316 MW. The power station is gas-fired with dual-fuel capability and is owned and operated by Premier Power Limited, a wholly owned subsidiary of BG Group. The 600 MW CCGT plant was commissioned in 2003 on a brownfield site adjacent to the existing Ballylumford plant. CCGT technology is significantly more efficient than a conventional generating plant, giving around 40% more electricity from the same amount of gas.

New information • Phase 2 Interconnector import flow expansion completed • Sale of equity stake in Interconnector (UK) Limited

Key dates 1997 Premier Power Limited converted from oil to natural gas 1998 Interconnector between UK and Belgium became operational 2000- Seabank Phases 1 and 2 entered 2001 full operation 2003 Completion of 600 MW CCGT plant at Premier Power 2005- Interconnector import flow 2007 expansions in three phases 2007 Sale of equity stake in Interconnector (UK) Limited Dragon LNG expected to be operational in the fourth quarter

BG Group Data Book 2007

SEABANK POWER LIMITED Built in two phases, Seabank is a 1 130 MW CCGT power station near Bristol. It is owned and operated by Seabank Power Limited, a 50:50 joint venture between BG Group and Scottish and Southern Energy. Phase 1 of Seabank (750 MW) entered full commercial operation in 2000 and Phase 2 (380 MW) in 2001. INTERCONNECTOR (UK) LIMITED In June 2007, BG Group sold its 25% shareholding in Interconnector (UK) Limited for £165 million. BG Group retains both import and export capacity in the pipeline, which runs from Bacton in England to Zeebrugge in Belgium. BG Group uses its capacity for long-, medium- and shorter-term sub-lets to third parties and also ships gas to take advantage of market price differentials. ENERGY MARKETING In 2006, BG Group produced 6.3 bcm gas from the UK Continental Shelf (UKCS), the equivalent to approximately 7% of UK gas demand. The Group sells gas on a wholesale basis at the entry to the National Transmission System (NTS) and ships gas via the NTS to sell at the National Balancing Point under long-, medium- and short-term contracts.

5

DRAGON LNG In 2004, BG Group and partners signed the shareholder and other related agreements to develop a £250 million LNG import terminal at Milford Haven in Wales. The agreements confirm the ownership of the terminal (BG Group 50%, PETRONAS 30% and 4Gas 20%) and the 20 year arrangements governing the use of capacity rights (BG Group 50%, PETRONAS 50%), allowing BG Group and PETRONAS to each send out 3 bcm (106 bcf) gas per year, from around 2.2 mtpa LNG.

Shareholders Dragon LNG (%)

BG Group PETRONAS 4Gas

EUROPE AND CENTRAL ASIA

BG Group is an active participant in the NTS entry capacity auctions held by National Grid and in the on-the-day commodity market and other electronic trading systems that help shippers balance their daily supply and demand. BG Group further optimises its portfolio through the use of rented gas storage capacity.

50 30 20

Dragon LNG is scheduled to be operational in fourth quarter 2007. MICROGEN BG Group subsidiary Microgen ceased operations in first half 2007. BG Group’s intellectual property rights relating to micro combined heat and power systems have been sold to Sunpower, Inc. of the USA.

BG Group Data Book 2007

Europe and Central Asia

UK Upstream

0

With interests in more than 20 UK Continental Shelf (UKCS) fields, BG Group has one of the most significant exploration and production businesses in the offshore waters of the UK. BG Group operates: the Armada fields (Fleming, Drake and Hawkins), the Maria field and the Seymour field in the central North Sea; the Blake and Atlantic fields in the Outer Moray Firth; and the Neptune, Mercury, Minerva and Apollo fields in the Easington Catchment Area (ECA) in the southern North Sea. In early 2007, the Buzzard field (Nexen-operated) in the Outer Moray Firth came onstream.

200km

SULLOM VOE

2 FLOTTA A

NORTH SEA ST. FERGUS ABERDEEN

1 3

TEESSIDE

IRISH SEA THEDDLETHORPE THEDDLE ETHORPE B BACTON

UK READING

LONDON

New information

UK: BG Group 3 year production Total production mmboe (net)

• Buzzard first oil

80

• Significant gas/condensate discovery in the Jasmine prospect

60

55.6

54.8

66.0

6

• Increased stakes in the Armada and Everest fields

Key dates

40

1997 Armada began production 20

1999 ECA Phase 1 first gas 2001 Blake first oil

0 04 Oil & liquids Gas

05

06

2002 ECA Phase 2 first gas 2003 Seymour first gas 2006 Atlantic/Cromarty first gas 2007 Buzzard first oil

BG Group believes there is significant remaining potential in the UKCS and is actively pursuing opportunities around existing infrastructure hubs. In addition to the core production hubs and exploration and appraisal interests on the UKCS, BG Group has a 51.18% interest in the Central Area Transmission System (CATS) offshore pipeline and onshore processing facilities, and a 7.86% stake in the Shearwater Elgin Area Line (SEAL). PRODUCING ASSETS Amethyst BG Group has a 24.15% interest in the BP-operated Amethyst field located in the southern North Sea. Amethyst East started production in 1990 and Amethyst West in 1991. The development’s four offshore platforms are unmanned, with production being controlled via the onshore terminal facilities. From the A2D platform, production is exported 40 kilometres via a dedicated 30-inch diameter line to the Easington terminal, where it is processed. The average daily rate in 2006 was 50 mmscfd. Amethyst gas is sold under a life of field contract. Armada/Seymour The BG Group-operated Armada gas condensate fields (Fleming, Drake and Hawkins) extend over 31 square kilometres and span five exploration blocks. Production began in 1997, following the successful completion of the Phase 1 project (facilities plus eight wells) on schedule and at a gross project cost of £437 million. Completed in 2002 at a gross cost of £76 million, the Armada Phase 2 drilling programme added a further three wells, extending the production plateau and lengthening the field life. An average rate of 187 mmscfd and 5 545 bopd was achieved in 2006. The SW Seymour area of the BG Groupoperated Seymour field (BG Group 57%

BG Group Data Book 2007

FR

IG

UK Upstream 1

Maria

E

Armada

W

AG

FLA

ES

GS

SAG

BRIT

ANN

Seymour

IA

FORTIE

Everest S

ST. FERGUS FULMAR

Lomond ABERDEEN

The commingled stream of Armada and Seymour gas is exported via the CATS pipeline to Teesside. Liquids are transported through the Forties Pipeline System (Forties) to the Kinneil processing plant at Grangemouth.

NORTH SEA

Glenelg

Jade

Key to operations

TS CA

100km

Key to operations

UK Upstream 2

Gas Oil

Buzzard BG Group has a 21.73% interest in the Buzzard oil field, located in the Outer Moray Firth 100 kilometres north-east of

EN BR

Gas pipeline Oil pipeline

SULLOM VOE

Bedlington

BG Groupoperated block BG Group non-operated block

SHETLAND ISLANDS

100km

IG

AG

G

S

0

FR

NORTH SEA

FLOTTA

Atlantic Blake

Buzzard ST. FERGUS

E

Armada

IA ANN BRIT FORTIES

Everest

FULMAR

LANG

ELED

UK Upstream 3

S AG

CATS

Cromarty

Neptune

Minerva

Apollo

NORTH SEA

Mercury EASINGTON

Amethyst THEDDLETHORPE

Key to operations Gas

Gas pipeline

BG Group non-operated block

BG Groupoperated block

0

50km

SEAL

Development of the second phase, Blake Flank, was completed and production commenced from two wells in second half 2003. This sub-sea development is tied back through the existing Blake facilities to the Ross FPSO vessel. An average total field rate of 24 000 bopd was achieved in 2006.

NINIAN

T

Faroe Island Licence

Blake and Blake Flank BG Group has a 44% interest in, and is operator of, the Blake field. The field is located 100 kilometres from Aberdeen in the Outer Moray Firth. First production was achieved in 2001, just 18 months after sanction, and the project was delivered 10% under budget. The field was developed in two phases. The first phase was the Blake Channel, which is a sub-sea development of six producing wells and two water-injection wells, tied back to an existing floating production, storage and offloading (FPSO) vessel located over the Ross field some 9.5 kilometres away.

LANG

Oil pipeline 0

FL

Atlantic/Cromarty BG Group has a 75% interest in the Atlantic field in the Outer Moray Firth. BG Group also holds 10% in the adjacent Cromarty field. The fields have been developed with three wells and a long sub-sea multiphase flow pipeline, the Western Area Gas Evacuation System (WAGES), tied into the SAGE terminal at St Fergus. Total investment was £235 million. Production began in June 2006, with a plateau rate of 220 mmscfd.

BG Group non-operated block

Gas pipeline

SEAL

Judy/Joanne

BG Groupoperated block

ELED

Gas Oil

On 30 March 2007, BG Group completed the purchase of ConocoPhillips’ 11.45% interest in the Armada fields, along with an increased stake in the Everest field, for a total consideration of US$143 million. This transaction increased BG Group’s shareholding in Armada to 58.22%.

Elgin

Franklin

BACTON

UK-Continent Interconnector

BG Group Data Book 2007

AND EUROPE AND ASIA CENTRAL ASIA

equity) was appraised successfully and drilled from the Armada platform in 2002. The gross project costs were £23 million and first production was achieved on 15 March 2003. A second well drilled in 2004 into the NW Seymour area was brought on production in April 2006 at a gross project cost of £44 million. This well produces black oil, the first of its kind across the Armada platform.

G

7

Europe and Central Asia 8

UK Upstream continued Aberdeen. The field was discovered in 2001 and came onstream in January 2007.

Partners Armada (%)

With total estimated proved and probable reserves of around 500 mmboe, the field is believed to be one of the largest discovered in the North Sea in more than ten years. Peak production is expected to be 190 000 bopd. Gross capex for the project was £1.5 billion.

BG Group (operator) BP Total Centrica

58.22 18.20 12.53 11.05

Partners Seymour (%)

The facilities consist of a three bridgelinked platform complex with oil export via Forties and gas export via the Frigg system. Peak annual production is scheduled for 2008. Easington Catchment Area (ECA) The Neptune, Mercury, Minerva, Apollo, Wollaston and Whittle gas fields in the southern North Sea are collectively referred to as the ECA. Neptune and Mercury are BG Groupoperated and were developed as the first phase of the ECA project. First production commenced in 1999.

BG Group (operator) Total Centrica

57 25 18

Partners Blake (%)

BG Group (operator) Talisman Petro Summit

BG Group Data Book 2007

44.0 53.6 2.4

The ECA Phase 1 facilities consist of a sub-sea production system at Mercury, a normally unmanned platform at Neptune, the ECA Riser Tower platform installed adjacent to the existing BP-operated Cleeton facilities and pipelines connecting the platforms and production systems. The Mercury sub-sea wells are tied back via a manifold and pipeline to the Neptune platform. The fluids produced from Mercury are commingled with fluids from the Neptune production wells before export to Cleeton for final separation, metering and transmission into the Southern North Sea Pipeline System infrastructure at the Dimlington processing terminal. BG Group holds 73.33% in Mercury and 79% in Neptune. Phase 2 of the ECA project consists of the BG Group-operated Minerva Hub fields, Minerva and Apollo (BG Group 65%), and the BP-operated Whittle Hub Fields, Wollaston and Whittle (BG Group 30.77%). Making use of the existing ECA infrastructure, the ECA Phase 2 facilities consist of a normally unmanned platform at Minerva and a sub-sea production manifold at Apollo, tied back to the Minerva platform. The platform exports all production to the ECA Riser Tower. The Wollaston and Whittle Field wells are tied back via a manifold and pipeline directly to the ECA Riser Tower. All production from the Minerva and Whittle Hubs is then commingled with Neptune and Mercury production at Cleeton. First production from the Whittle Hub commenced on 31 December 2002, with first production from the Minerva Hub following shortly

after, in January 2003. A combined average production rate of 160 mmscfd was achieved by ECA during 2006. Elgin/Franklin Area The Elgin/Franklin high pressure and high temperature (HPHT) gas condensate fields are located in the central North Sea. Following their £1.7 billion (gross) joint development, the fields began production in 2001. A total of 12 wells, six each in Elgin and Franklin, produced at an average rate of 440 mmscfd and 90 600 bopd during 2006. A seventh well has been completed on Franklin and entered production during second quarter 2007. Total operates the Elgin/Franklin fields in which BG Group has a 14.11% interest. A separate field, West Franklin, is expected to start production in third quarter 2007. Drilling of a second well has commenced on this field, production from which is expected to start in second half 2008. The HPHT Glenelg field (BG Group 14.7%), in Block 29/4d, started production in March 2006. The field has been developed through a single high departure well drilled from the Elgin wellhead platform. Elgin/Franklin and Glenelg gas is exported through SEAL, a common export pipeline shared with the nearby Shell-operated Shearwater field, to the onshore gas reception facilities at Bacton in Norfolk. Gas then flows into the NTS or via the Interconnector into Europe. Liquids are exported through Forties to the Kinneil processing plant at Grangemouth. Gas and liquids from West Franklin will follow the same export routes. Everest and Lomond Also situated in the central North Sea are the BP-operated Everest and Lomond fields. BG Group holds a 59.32% stake in Everest, increased following the purchase in December 2006 of ConocoPhillips’ 1.01% stake, and a 61.11% interest in Lomond. The fields were developed in parallel, with first production in 1993. In 2001, two additional wells were added to each of Everest and Lomond as part of the four well Phase 2 programme. These wells extended plateau production levels and accessed reserves in South Everest. Drilling of two further wells is currently ongoing on Everest. A combined average production rate of 208 mmscfd and 5 000 bopd was achieved in 2006. Everest and Lomond gas is exported via the CATS pipeline and is sold under contract to Teesside Power Limited. Produced liquids go via the Forties pipeline to Kinneil.

9

Jade was developed using a normally unmanned wellhead platform and currently produces from six wells. The Jade South West exploration well, drilled from the Jade platform, was successful and was brought on production during June 2006. Production from Jade is exported via a sub-sea pipeline to the manned Judy platform where it is commingled and processed with Judy and Joanne production. The combined gas stream is then exported via the CATS pipeline to Teesside and the combined liquids stream exported via Norpipe to the Norsea oil terminal at Teesside. The Judy/Joanne fields currently produce from 19 wells, three of which were brought into production in 2006. A further successful Jade exploration well was drilled in second quarter 2006. In 2006, after an exploration well and sidetrack by the operator ConocoPhillips, BG Group announced a substantial commercial hydrocarbon accumulation – the Jasmine discovery. The initial well was drilled nine kilometres west of the existing Judy development. BG Group estimates recoverable reserves to be between 100 and 275 million barrels and further exploration activity is planned in the area in 2007. DEVELOPMENT FIELDS Maria In 2003, BG Group assumed operatorship, on behalf of a consortium with Total and Centrica, of the fallow Maria 16/29a-11Y discovery. An appraisal well drilled in 2004 identified a 900-foot oil column and confirmed the viability of the discovery. Sidetrack drilling then confirmed an extension into the adjacent Maria Horst prospect.

UKCS EXPLORATION In the 24th licensing round announced in February 2007, BG Group was awarded a total of three blocks adjacent to existing acreage positions close to the Lomond field (22/25d, BG Group 100%) and the Jackdaw discovery (23/27b, BG Group 100% and 30/3b, BG Group 30.5%).

Partners Buzzard (%)

BG Group has increased its equity in exploration acreage in Block 22/14a to 41.27% via the purchase of ConocoPhillips’ equity. OFFSHORE PIPELINES CATS BG Group has a 51.18% interest in the CATS pipeline and terminal, which is operated by BP. The 404 kilometre 36-inch diameter CATS offshore pipeline became operational in 1993 and now transports gas to Teesside from the Everest, Lomond, Andrew, Armada, Seymour, Judy/Joanne, Jade, Erskine, Banff and Eastern Trough Area Project (ETAP) fields (all in the central North Sea). The pipeline has a peak gas capacity of around 1 700 mmscfd.

BG Group 21.73 Nexen (operator) 43.21 PetroCanada 29.89 Dyon 5.16 Figures rounded to 2 decimal places

Onshore, the CATS Teesside terminal includes two trains of gas processing equipment for Armada, Seymour, Erskine, ETAP and Banff fields. Train 1 became operational in 1997, originally for Armada and Erskine, and Train 2 was brought onstream in 1998 for ETAP and Banff. The total processing capacity of the terminal is around 1 200 mmscfd. The CATS owners have recently contracted additional business from the Maria and Montrose Arbroath fields. SEAL and SILK BG Group has a 7.86% interest in SEAL, a 480 kilometre 34-inch diameter gas export pipeline to Bacton. The pipeline was completed in 2000 for the Elgin/Franklin and Shearwater fields. With capacity of around 1 150 mmscfd of NTS-quality dry gas, it has been transporting gas since 2001. BG Group also has a 15.98% interest in the 900 metre 34-inch diameter SEAL Interconnector Link (SILK) pipeline that provides direct access from SEAL into the UK-Continent Interconnector pipeline.

Production from Maria will be tied back to Armada, with gas exported via CATS to Teesside and liquids through Forties to the Kinneil processing plant at Grangemouth. First production is scheduled for third quarter 2007.

BG Group Data Book 2007

AND EUROPE AND ASIA CENTRAL ASIA

J-Block and Jade The ConocoPhillips-operated Judy/Joanne (J-Block) (gas condensate/oil) and Jade (gas condensate) fields are located in the central North Sea. BG Group has a 30.5% interest in J-Block and a 35% interest in Jade. Production began from J-Block in 1997 and from Jade in 2002. The 2006 combined average production rate from the fields was 577 mmscfd and 44 500 bopd.

Europe and Central Asia 10

Norway Key to operations

PL396 PL396 PL395 PL395

Gas

Oil pipeline

Oil

BG Groupoperated block

Gas pipeline

PL393 PL393

Pipeline – proposed or under construction

NORWAY

0

BG Group non-operated block

500km

PL392 PL391 PL324

PL382

PL325 PL388

PL390 Langeled Pipeline

KRISTIANSUND

PL251 PL372BS PL374S PL373S

NYHAMNA

PL372S

NORWAY

SWEDEN

PL423S HAUGESUND STAVANGER

PL407 PL292 PL335

UK

PL274BS

PL143 PL297

New information • Awarded two new licences in 2006 Awards in Pre-defined Areas (APA) Licence Round, including the Bream oil discovery • Completion of the Nucula, Barents Sea exploration well

Key dates 2004 BG Group acquired first licence, PL297 BG Group opened office in Stavanger 2005 Completion of the Tulipan exploration well, BG Group’s first Norway well 2006 Awarded eight licences in the 19th Licensing Round 2007 Awarded operatorship of the Bream licence (PL 407) Completion of the Nucula exploration well, BG Group’s first Barents Sea well

BG Group entered Norway in 2004, with the award of PL297 (Mandarin) in the North Sea. The Group now has 22 licences (14 as operator), gained predominantly through licensing rounds and located in four established core areas. A significant exploration programme will be undertaken in 2007, with four exploration wells scheduled for completion plus extensive 3D seismic acquisition. Planning for appraisal drilling on the Bream oil discovery is underway in preparation for 2008 drilling. SOUTHERN NORTH SEA (6 licences, 5 operated) This was the entry point into Norway, with BG Group applying its UK Central Graben expertise and experience to the Norwegian median line area. Many of the plays being explored in the Norway licences are similar to those developed and matured in the UK. Two operated exploration wells are scheduled for completion in 2007, Orange and Pi North. A commitment has been made for the drilling of the high pressure/high temperature Mandarin prospect, scheduled for 2008. In January 2007, BG Group was awarded the PL407 licence as operator, which contains the Bream oil discovery. The drilling of an appraisal well on Bream is scheduled for 2008.

BG Group Data Book 2007

NORTH TAMPEN (5 licences, 4 operated) A 3D seismic survey was acquired over the Plomme prospect (PL 372S) in 2006, which will be used to determine any future drilling plans. Planning continues on the BG Group-operated Jordbær exploration well (PL 373S). One further licence was gained through the award of PL423S in the 2006 APA Licence Round, and a 3D seismic survey is scheduled for 2007. MID-NORWAY (8 licences, 4 operated) BG Group holds a significant position in this area, including a number of deep water licences (over 1 000 metres water depth), and drilled its first commitment well in this area this year. In addition, in 2007, BG Group will complete two large operated 3D surveys covering three licences in the Rås Basin area. The data will determine if an exploration well is to be drilled on these licences. BARENTS SEA (3 licences, 1 operated) BG Group completed its first Barents Sea well in March 2007 as a participant in the Hydro-operated Nucula well located in PL393. This well is an oil and gas discovery and post-well work continues to determine any appraisal requirement. Nucula is located less than 50 kilometres from the coast in an environmentally sensitive area, and the well was drilled under strict conditions less than a year after being awarded.

Europe and Central Asia

Italy

11

SLOVENIA

MILAN

CROATIA

TURIN RIVALTA

BOSNIA & HERZEGOVINA

Po Valley

ITALY A ADRIATIC SEA ROME

SULMONA

TERMOLI

Brindisi LNG

CASSINO NAPLES

MELFI

BRINDISI

TYRRHENIAN SEA

MEDITERRANEAN SEA IONIAN SEA

Key to operations Gas

Oil pipeline

Oil

BG Groupoperated block

TUNISIA

Gas pipeline

0

LNG BG Group is developing an 8 bcma (6 mtpa) LNG import terminal in the outer harbour of the port of Brindisi (BG Group 100%). The EPC contract was awarded in 2004. Offsite works began in early 2005, followed by onsite works in second half 2005. BG Group will have the rights to 80% of the capacity in the terminal on a priority basis, whilst the remainder will be subject to regulated third-party access. The terminal is strategically located to receive LNG from the Mediterranean and Atlantic Basins and the Gulf States. In February 2007, the Brindisi LNG site was seized in connection with a criminal investigation by Italian authorities into allegations of improper conduct related to the authorisation process. Construction work has been suspended since this date. It is unclear at this stage how this investigation and other matters described in the BG Group’s Annual Report and Accounts 2006 may affect the project. EXPLORATION BG Group has focused recent exploration activity in the Po Valley, where the Group holds six exploration permits (five operated) and one licence application.

250km

New information • Ownership of Serene S.p.A. power plants increased to 100%

Key dates 1998 Serene S.p.A. power stations began operation 2004 Brindisi LNG EPC awarded 2006 Italian authorities and European Commission confirmed 20% third-party access at Brindisi LNG Construction of Brindisi LNG began 2007 Ownership of Serene S.p.A. power plants increased to 100% BG Group has been active in Italy since 1992. Italy is a major net importer of gas, a commodity upon which it is becoming increasingly dependent as the government focuses on environmentally friendly energy sources. BG Group seeks to position itself within the Italian market to supply this rising demand.

POWER In February 2007, BG Italia acquired the remaining 66.32% of Serene S.p.A. shares from Edison for €98 million, which increased BG Group’s interest in Serene S.p.A. to 100%. The company owns and operates approximately 400 MW of co-generation at five locations adjacent to Fiat Auto factories. Three 100 MW power stations are located at Melfi, Termoli and Cassino, with the 50 MW stations at Sulmona and Rivalta. The plants have been in operation for eight years and are located to supply steam to Fiat Auto plants and other adjacent steam offtakers. Serene S.p.A. supplies nearly 3 000 GWh per year of electricity to the grid operator, GRTN, and 340 000 tonnes of steam, primarily to Fiat. Fuel gas is supplied to the plants by Eni and Edison.

Current activity in Italy includes: E&P, where BG Group holds exploration permits in the Po Valley; LNG, where BG Group is developing a LNG import terminal on the south-eastern coast; and Power, where BG Group owns and operates five co-generation plants.

BG Group Data Book 2007

AND EUROPE AND ASIA CENTRAL ASIA

HUNGARY

Europe and Central Asia

Kazakhstan Key to operations Gas and Oil/Condensate Gas pipeline ORENBURG

Oil pipeline

0

500km BOLSHOI CHAGAN

Karachaganak

Atyrau Samara pipeline

UKRAINE

Karachaganakto-CPC pipeline

KAZAKHSTAN CPC

RUSSIA

ATYRAU

ASTRAKHAN

CPC

TENGIZ

NOVOROSSIYSK

AKTAU

BLACK SEA GEORGIA

Kazakhstan: BG Group 3 year production

CASPIAN SEA

New information

40

• Agreed terms of the Phase III Gas Sales Agreement

36.3

• Fourth stabilisation train sanctioned

35.0

Total production mmboe (net)

30.7

12

30

Key dates

20

1996 Acquired 2% stake in restructured Caspian Pipeline Consortium (CPC)

10

1997 Karachaganak and North Caspian PSAs signed 2001 CPC fully operational

0 04 Oil & liquids Gas

05

06

2003 First liquids from new Karachaganak facilities 2004 Phase II Karachaganak development completed. First exports via Novorossiysk on the Black Sea 2005 Completed sale of interest in North Caspian Sea PSA 2006 Oil exports commenced via the Atyrau Samara pipeline 2007 Agreed the terms of the Phase III Gas Sales Agreement with KazRosGaz

BG Group Data Book 2007

BG Group has been active in Kazakhstan for 15 years. It is joint operator of the giant Karachaganak gas condensate field in north-west Kazakhstan, where it has a 40 year concession, and a shareholder in the Caspian Pipeline Consortium (CPC). The CPC pipeline links reserves in western Kazakhstan to the Black Sea, providing access to world markets. KARACHAGANAK The Karachaganak field, discovered in 1979, is one of the world’s largest gas and condensate fields. Located in north-west Kazakhstan, it holds HIIP of 9 billion bbls of condensate and 48 tcf of gas, with estimated gross reserves of over 2.4 billion bbls condensate and 16 tcf of gas. Since the signing of the Final Production Sharing Agreement (FPSA) in 1997, the Karachaganak partners have made substantial investment in wells, facilities and pipelines. In addition to its size, Karachaganak presents the operators with formidable challenges due to extreme climate swings (+/- 40 degrees centigrade) and the requirement to reinject high pressure sour gas. BG Group’s share of production from Karachaganak in 2006 was 36.3 mmboe, an increase from 35 mmboe in 2005. A record daily production of 440 000 boe was achieved on 5 November 2006. Production from the Karachaganak field began in 1984 when Kazakhstan was still part of the Soviet Union. BG Group first investigated the possibility of investing in the field in 1990, and in 1992 the Kazakhstan authorities granted BG Group and Agip (now Eni) exclusive rights to negotiate a development agreement. In 1995, a Production Sharing Principles Agreement (PSPA) was signed under which BG Group and Agip took over operatorship of the field in order to halt rapid production decline and to improve the safety and environmental performance of the facilities. Texaco (now Chevron) acquired a 20% share in Karachaganak from BG Group and Agip in August 1997, and two months later LUKoil took a 15% share that was formerly held by Gazprom. In November 1997, the FPSA was signed (effective 27 January 1998), superseding the PSPA and providing for the full development of the field. The FPSA envisaged a phased development programme, of which the first two phases have been completed. Phase II involved investment of over US$ 1 billion (net BG Group) to enhance the existing facilities, construct new gas and liquids processing and gas injection facilities, work-over more than 100 wells, construct a 120 MW power station and lay

13

Phase II facilities came fully onstream in 2004. Historically, virtually all production was sold into Russia, but now most liquids are sold via the CPC (currently around 70%), with some condensate and all sales gas continuing to be sold into Russia. Exports via the CPC pipeline have achieved international prices that are substantially higher than those secured in the Russian market. An additional oil export route, via the Atyrau Samara pipeline leading into the Russian Transneft system, subsequently became available, and oil exports through this route began on 19 June 2006, enabling additional sales at international prices. The Phase IIM drilling programme, incorporating an additional 16 production wells, was sanctioned in 2005. A fourth stabilisation train project, sanctioned in December 2006, has been expanded to include 13 additional wells and a rail export facility with an initial capacity of 3.8 mtpa. This will increase Western export volumes to more than 10 mtpa and develop gross reserves of 250 mmboe. It is expected to be onstream in 2009. In November 2006, pre-FEED work for the Phase III development of the Karachaganak field was completed. Further work is now underway, designed to increase liquids and gas production rates and to recover additional reserves. At an expected investment of around US$8 billion (gross), Phase III is targeted to come onstream in 2012, and is expected to increase liquids sales to 16.5 mtpa and gas sales to 16 bcma. In June 2007, BG Group and partners agreed the terms of the Phase III Karachaganak Gas Sales Agreement with KazRosGaz, a joint venture between Gazprom and KazMunaiGaz. The agreement, which is subject to approvals, sets out the commercial terms governing the sale of gas over a 15 year period and is expected to commence fourth quarter 2007. CASPIAN PIPELINE CONSORTIUM (CPC) The CPC was formed to build a pipeline system to transport oil from western Kazakhstan to the Black Sea near Novorossiysk in Russia. The pipeline system, which commenced operations along its full length in 2001, consists of a new-build line, new marine terminal facilities near Novorossiysk and an upgraded pipeline. The first phase of the system, known as the Initial Construction Project (ICP), has a capacity of 28.2 mtpa (560 000 bopd), all of which has been allocated to CPC shareholders. However, CPC is able to accept more oil than initially expected (now in excess of

30 mtpa) as a result of improved operating efficiency. The ICP cost around US$2.6 billion to complete, of which BG Group contributed approximately US$70 million.

Partners Karachaganak (%)

AND EUROPE AND ASIA CENTRAL ASIA

a new 650 kilometre pipeline to connect the field to the CPC pipeline at Atyrau.

Karachaganak, operating via the Karachaganak Petroleum Operating Company (KPO), began delivering liquids into CPC in 2004. BG Group has a 2% equity share in the line but is entitled to 2.75 mtpa (55 000 bopd) of CPC initial capacity (around 10% of the total) which, along with other Karachaganak partners’ entitlements, is being used to transport liquids from the Karachaganak field. An expansion of the pipeline system to over 60 mtpa is the next step, and FEED and CPC shareholder discussions related to this are ongoing. The first phase of expansion will increase BG Group’s preferential capacity rights to 3 mtpa (60 000 bopd), and there is potential to increase the total gross capacity of the pipeline to some 67 mtpa (1.45 million bopd) over time. In 2006, liquids from Karachaganak yielded 78 tanker loadings, lifting 6.6 million tonnes (52 million barrels) at Novorossiysk.

BG Group ( joint operator) Eni ( joint operator) Chevron LUKoil

32.5 32.5 20.0 15.0

Shareholders CPC (%) BG Group Russian Government Kazakh Government Chevron LUKARCO ExxonMobil Rosneft-Shell Omani Government Eni Oryx KPV

2.00 24.00 19.00 15.00 12.50 7.50 7.50 7.00 2.00 1.75 1.75

Karachaganak: Additional export capacity secured

Rail

Orenburg

0 mtpa

8 bcm

5.1 mtpa

16 bcm

Atyrau Samara

Orenburg

2 mtpa

4 mtpa

3.3 mtpa

4 mtpa

Karachaganak field

Gas re-injection

CPC

Small Refinery

7 mtpa*

0.4 mtpa

7 mtpa

0.4 mtpa

Stabilised Oil

Un-stabilised Oil

Capacity 2006

Gas

Stabilised Oil future route

Planned Capacity 2012

*6.5 mtpa firm capacity plus access to additional capacity

South America 14

Argentina, Bolivia, Chile and Uruguay Key to operations

Argentina

BOLIVIA

Gas

Key dates

PARAGUAY

Oil

BRAZIL

Gas pipeline 0

500km

1994 MetroGAS Initial Public Offering on NYSE

ARGENTINA

2002 Devaluation of Argentine Peso. MetroGAS suspends payments of principal and interest on its debt

MetroGAS

GNL Quintero

SANTIAGO

BUENOS AIRES

URUGUAY MONTEVIDEO

Southern Cross and Gas Link pipelines operational

CHILE PACIFIC OCEAN C CEAN

1992 Purchase of MetroGAS distribution licence

2005 MetroGAS deconsolidation from BG Group’s accounts

Southern Cross and Gas Link Pipelines

Launch of MetroENERGIA gas marketing 2006 MetroGAS debt-restructuring completed ATLANTIC OCEAN

METROGAS MetroGAS is the largest natural gas distribution company in South America. BG Group acts as technical operator. MetroGAS supplies approximately two million customers in the city of Buenos Aires, and in 2006 delivered 8 bcm gas through 16 016 kilometres of pipelines.

MetroGAS effective shareholders (%) (following completion of GASA restructuring, which remains subject to regulatory approvals)

In January 2002, the Argentine government declared what it called a state of “public emergency”, forcing the re-negotiation of public utility contracts. The timing and outcome of this process still remains uncertain. As a result, in March 2002, MetroGAS and its holding company – GASA – suspended payments on all of its financial debt. In November 2003, MetroGAS launched a debt-restructuring plan.

BG Group Gas Argentino S.A. (GASA)*

6.80 51.00

Marathon Funds

15.35

Retail Former Gas del Estado employees

13.20

Ashmore Funds

10.00 3.65

* GASA (BG Inversiones Argentinas 38.3%; YPF Inversora Energética 31.7%; Ashmore Internacional Utilities 30.0%)

In December 2005, GASA reached agreement with its creditors for a comprehensive restructuring, subject to regulatory and local competition authority approvals. The agreement will reduce BG Group’s interest in GASA to 38.3%, thereby lowering its indirect shareholder interest in MetroGAS to 19.5%. Given that BG Group maintains a 6.8% direct interest in MetroGAS, its total stake will then represent 26.3%. This agreement led to the deconsolidation of MetroGAS from BG Group’s accounts in 2005. In May 2006, MetroGAS reached a successful outcome of the debtrestructuring process, with a 95% level of consent from its creditors, increased to 99.5% by December 2006, following several court rulings.

BG Group Data Book 2007

15

Bolivia

Key to operations Gas

BG Groupoperated block

New information

BG Group non-operated block

• New Operation Contracts signed in October 2006

Oil Gas pipeline Oil pipeline

• Contracts came into effect in May 2007

0

100km

Charagua

Key dates 1998 Discovered Margarita 1999 Itau field discovered Purchased Bolivian assets from Tesoro

BOLIVIA Margarita

2004 First production from Margarita Early Production Facility

La Vertiente

2005 New hydrocarbons law passed in May

Ibibobo-Mistol VILLAMONTES

TARIJA

Tarija XX East

Tarija XX West

Palo Marcado

Itau

Tarija XX East

2006 Supreme Decree (No. 28701/6) on Nationalisation issued in May

Los Suris

BG Group has six exploration/ exploitation and retention blocks (which hold discoveries that have not yet commenced production) and holds a participating interest in Itau and Margarita, two of the largest discovered gas condensate fields in the country.

PARAGUAY ARGENTINA

Bolivia: BG Group 3 year production

Partners Caipipendi Block (Margarita) (%)

Total production mmboe (net)

6.2

8

4.1

5.3

6 4 2 0 04

05

06

BG Group Repsol YPF (operator) Pan American Energy

37.5 37.5 25.0

Oil & liquids Gas

Partners Itau Tarija XX West Block (Itau Retention Area) (%)

Bolivia enacted a new hydrocarbons law on 19 May 2005, following a national referendum held on 18 July 2004 covering gas exports, hydrocarbon taxes and the management of the hydrocarbon sector. On 1 May 2006, the Government issued a nationalisation Supreme Decree. The law and the nationalisation Supreme Decree provide that ownership of the production at the wellhead reverts to the State, mandated a renegotiation of concession contracts within 180 days, created a new, non-creditable, 32% royalty-type tax on wellhead production, and provided for increased state control over the sector. In compliance with such provisions, on 28 October 2006, BG Group and partners signed four new Operation Contracts with YPFB. Following congressional approval and subsequent notarisation on 2 May 2007, these contracts became effective, replacing the existing shared risk contracts. Bolivian production represented around 3% of Group production in 2006. Through delivery arrangements with YPFB, BG Group and its partners supply gas from fields in La Vertiente, Los Suris and Caipipendi blocks to Brazilian and domestic markets.

BG Group Total Bolivie (operator)

25 75

100% OPERATIONS Following the acquisition in December 1999 of Tesoro Bolivia Petroleum Company, BG Group continues to hold and operate (100%) several exploitation and retention licences containing six gas condensate fields. BG Group Data Book 2007

SOUTH AMERICA

Caipipendi

LA PAZ

South America 16

Argentina, Bolivia, Chile and Uruguay continued La Vertiente The 375 square kilometre La Vertiente exploitation block contains the La Vertiente, Escondido and Taiguati gas condensate fields. Production from La Vertiente began in August 1978 and from Escondido in October 1989.

Chile

Los Suris The 50 square kilometre Los Suris exploitation block contains the Los Suris gas condensate field which began production in August 1999.

Key dates

XX Tarija East Two discovered gas condensate and oil fields, Ibibobo and Palo Marcado, have been held as Retention Areas awaiting development. NON-OPERATED BLOCKS Caipipendi BG Group has a 37.5% equity share in this Block which contains the large Margarita gas condensate field lying in the 874 square kilometre Margarita exploitation area. Following discovery in November 1998, the Margarita X2 and X3 appraisal wells were drilled in 1999 and the X4 appraisal well successfully tested gas in May 2004. First production from Margarita began in December 2004 under an interconnection agreement with Petrobras for the temporary use of its gas and liquids lines. The Caipipendi block also contains several large gas condensate exploration leads and prospects. XX Tarija West BG Group has a 25% interest in the XX Tarija West block, which contains the Itau gas condensate field currently in retention. Charagua BG Group has a 20% interest in the 787 square kilometre Charagua Block which contains the Itatiqui Retention Area.

New information • GNL Quintero LNG import terminal project sanctioned in June 2007 • Terminal construction has commenced

2006 BG Group selected to develop a LNG import terminal and supply Chile Project Development Agreement (PDA) signed for the construction of, and supply to, a LNG regasification plant in Chile 2007 GNL Quintero SA incorporated and project sanctioned CHILE LNG In March 2007, BG Group and partners incorporated GNL Quintero SA and executed the relevant shareholder agreement. GNL Quintero SA will implement, operate and own a 2.5 mtpa LNG import terminal to be located in Quintero Bay, 110 kilometres from Santiago. The regasification plant will include two 160 000 cubic metre LNG storage tanks and will have an initial send-out capacity of 340 mmscfd on a sustainable basis and 510 mmscfd on a peaking basis, meeting approximately 40% of the country’s demand for natural gas. Following project sanction, BG Group and the partners awarded the US$775 million EPC contracts to Chicago Bridge & Iron Company in June 2007. GNL Quintero SA is progressing with the construction of the terminal, which is scheduled to be fully operational in second quarter 2010, with early operations scheduled for second quarter 2009. The GNL Quintero SA partners have secured capacity rights in the terminal and have arranged to off-take the gas via 21 year agreements with 1.7 mtpa LNG supplied by BG Group from its supply portfolio.

Uruguay BG Group is operator with a 40% share in the Southern Cross Pipeline (SCP) linking Argentina to Montevideo. The pipeline became operational in November 2002 at the start of a 30 year concession period. Through its holding in Dinarel, BG Group holds a 25.5% interest in Gas Link, a 40 kilometre gas pipeline connecting the SCP to the Argentine transportation network.

BG Group Data Book 2007

Shareholders GNL Quintero SA (%)

BG Group ENAP Endesa Metrogas S.A. of Santiago

40 20 20 20

South America

Brazil

17

The concession area has a population of over 29 million and Comgas anticipates continued growth opportunities in future.

BT-SF-2

BG Group has an equity position in the Bolivia-Brazil Pipeline (BBP) and in seven offshore exploration licences in the Santos Basin, which includes the Tupi discovery made in 2006, and one licence onshore.

Bolivia-Brazil Pipeline BELO HORIZONTE

Comgas

BRAZIL

RIO DE JANEIRO

SÃO PAULO

Parati BM-S-9, 10, 11

CURITIBA

Tupi BM-S-47

BM-S-13

ARGENTINA

Key to operations Gas

PORTO ALEGRE

URUGUAY

BG Groupoperated block

Oil Gas pipeline

BG Group non-operated block

Oil pipeline

Licenced block

0

500km

New information

Partners Tupi (BM-S-11)(%)

• Oil and gas discovered in Parati (BM-S-10) and Tupi (BM-S-11). Exploration and appraisal of deep water Santos blocks continues • Record volumes at Comgas in first half 2007

BG Group Petrobras (operator) Petrogal

25 65 10

• Iqara has installed a further 14 Compressed Natural Gas filling stations primarily in the states of Rio de Janeiro and São Paulo, taking the total to 68

Key dates 1999 Purchased controlling stake in Comgas Bolivia-Brazil pipeline connected to São Paulo 2005 Drilling programme began in deep water Santos Basin 2006 Secured ten new exploration blocks in the ANP 7th licensing round now consolidated into four new licences Brazil is a central part of BG Group’s South America strategy. BG Group has a controlling stake in Comgas, which is Brazil’s largest gas distribution company. Comgas has over 500 000 customers in São Paulo and increased the volume of gas distributed in 2006 by 9.7%.

In July 2004, BG Group acquired a 100% operated interest in the BM-S-13 exploration block in the shallow water (100 to 200 metres water depth) Santos Basin. Entry to the Second Exploration Period commenced 28 September 2004. In May 2006, BG Group completed its first two operated wells in BM-S-13 and in September 2006, BG Group entered the third and final two year Exploration Period with a commitment to acquire further 3D seismic. In October 2005, BG Group´s exploration portfolio was further extended following success in the 7th Annual Brazil licensing round. Three licences were awarded in the offshore Santos Basin (BM-S-47, BM-S-50 and BM-S-52) and one onshore licence was awarded in the São Francisco Basin in Minas Gerais State (BT-SF-2). BOLIVIA-BRAZIL PIPELINE (BTB) With total capacity of 30 mmcmd, the BTB is 3 150 kilometres long, of which 2 593 kilometres is in Brazil. The project was developed through two different companies: Gas Transboliviano (GTB), which owns and operates the assets in Bolivia, and Transportadora Brasileira Gasoduto Bolivia Brasil (TBG), which owns and operates the Brazilian portion of the pipeline. Operation of the two BG Group Data Book 2007

SOUTH AMERICA

BM-S-50, 52

PARAGUAY

EXPLORATION On 15 September 2003, BG Group entered the Second Exploration Period for the nonoperated BM-S-9, 10 and 11 blocks in the deep water (greater than 2 000 metres water depth) Santos Basin. In September 2006, the Parati well drilled by Petrobras in BM-S-10 (BG Group 25%) and the Tupi well also drilled by Petrobras in BM-S-11 (BG Group 25%) were both declared as discoveries. Tupi is a large structure with significant reserves potential requiring further appraisal drilling and evaluation. Initial estimates by BG Group and partners are that Tupi could contain from 1.7 billion boe to more than 10 billion boe gross hydrocarbons in place. The Tupi well flowed 4 900 bbls per day of sweet 30 API crude oil and 4.3 mmscfd of gas from a deep pre-salt reservoir on a 5/8th inch choke. Both BM-S-10 and BM-S-11 are now in an Evaluation Period with appraisal of the Tupi discovery commencing in second quarter 2007. Drilling on BM-S-9 also commenced in the second quarter 2007.

South America 18

Brazil continued pipelines is co-ordinated through an Interconnection Agreement.

Effective shareholders BTB (%)

BG Group Petrobras Transredes El Paso Enron Shell Total

7.65 40.46 22.27 7.65 7.42 7.42 7.12

Figures rounded to 2 decimal places and is a result of adding GTB’s and TBG’s equity positions

BG Group participates in TBG through BBPP Holdings, together with El Paso and Total. BG Group’s one-third equity in BBPP Holdings represents a 9.67% interest in TBG. BG Group holds a 2% interest in GTB. Based upon the cost of the two sections of BTB, BG Group has an effective overall interest of 7.65%, although this does not represent a direct equity holding, as GTB and TBG are two separate entities. Construction of the pipeline was completed in March 2000, at a cost of US$2.2 billion, opening the Brazilian energy market to Bolivian gas reserves. COMGAS Summary of Comgas 2006 results: • 9.7% increase in the total volume of gas sales • 12.5% increase in industrial segment sales

Effective shareholders Comgas (%)

• 18.1% increase in gas sales to Natural Gas Vehicle (NGV) market • 463 kilometres of network expansion BG Group, has a controlling interest in Comgas, Brazil’s largest gas distribution company. Comgas is listed on the São Paulo stock exchange with a freefloat of 21.80%.

BG Group Public Shell

60.04 21.80 18.16

Comgas distributed volumes (bcma) Comgas volumes have grown at a CAGR of 11.7% between 2003 to 2006 5

Comgas was founded in 1872, and at the end of 2006 had 4 720 kilometres of pipelines covering 60 municipalities and supplied gas to 960 industrial, 8 361 commercial and 508 116 residential customers in the state of São Paulo. Additionally, Comgas supplied 369 NGV filling stations and 15 customers in the thermo generation and co-generation market. Comgas has increased the average daily volume from 3.0 mmcmd in 1999 to 13.0 mmcmd in 2006. Comgas increased its total net income by 33.9% to BRL 427.4 million in 2006 and invested BRL 426.5 million.

4 3 2 1 0 03

04

Industrial Residential Commercial NGV Co-generation Thermal

BG Group Data Book 2007

05

06

BG Group and Shell have been the majority shareholders in Comgas since April 1999, when the state-owned power generation utility, Companhia Energética São Paulo, sold its controlling stake in Comgas. Integral Investments paid BRL 1 653 million (US$988 million) for 62.7% of the company, which in turn is controlled by BG São Paulo Investments B.V. (96%) and Shell Gas B.V. (4%). Shell incorporated its previously held 15.6% shareholding in the company into the controlling consortium. The Comgas concession is a 30 year franchise, with a potential for a further 20 years. The concession area contains

Financial and Operating Summary – Comgas 2006

Revenue (£ million) 738.6 EBIT (£ million) 186.2 Customers at year end (‘000) 517 Sales volume (mmcm) 4 773

2005

2004

532.0

397.0

147.0

80.0

485

451

4 346

3 418

7.7 million households and is in the industrial heartland of Brazil, accounting for about 25% of Brazil´s GDP. The current business focus continues to be the connection of higher margin commercial and residential customers. The concession contract requires a tariff review every five years. The first, concluded in May 2004, defined the overall level and structure of tariffs for the period June 2004 to May 2009, and allows Comgas to make sufficient return to support further investment and growth in the business. Since the last tariff review (2004), Comgas has invested more than BRL 1 082 million. Comgas purchases gas at prices indexed to a basket of oil-related fuels. Brazilian gas supplies from Petrobras of 3.0 mmcmd are contracted until December 2007. Bolivian gas supplies from Petrobras began in July 1999 under a 20 year contract, with volume increasing from 4.0 mmcmd in 1999 to 8.7 mmcmd in 2006. In addition, in December 2002, Comgas signed an extension to the existing agreement between BG Group and Comgas, resulting in the purchase of up to 0.65 mmcmd of gas until 2011, under a firm contract. This agreement is currently being renegotiated in order to adapt it to the new Bolivian regulatory regime. NEW BUSINESS Iqara Gas Natural, launched in 2001, provides compression services to the rapidly growing Brazilian NGV market. There are currently 68 Iqara Gas Natural CNG service stations, primarily located in the states of Rio de Janeiro and São Paulo. BG Group continues, through Iqara Energy Services, to expand the provision of energy solutions (co-generation, peak shaving electric power generation, chilling and heat generation) tailored to clients’ specific needs using natural gas as the primary fuel. In the first half 2007, a total equivalent to 48.1 MW have been signed of which 33.0 MW are under construction.

Asia Pacific

India

19

New information

Key to operations AHMEDABAD

Gas

• 10.3 mmboe net production from the expanded Panna/Mukta and Tapti fields in 2006

BG Groupoperated block

Oil BG Group non-operated block

Gas pipeline 0

• Signed a Production Sharing Contract with the Government of India for Block KG-OSN-2004/1 in 2007

VADODARA

100km

BHARUCH

Key dates

ANKLESHWAR

GGCL transmission pipeline Gujarat Gas

HAZIRA

1997 Acquired majority stake in Gujarat Gas Company Ltd (GGCL)

SURAT

Tapti Tapti gas pipeline

INDIA

GULF OF CAMBAY

Panna

Mukta

MUMBAI

India 1

1

INDIA

2

ANDHRA PRADESH

KG-OSN-2004/1

India 2

India: BG Group 3 year production

9.4

12 8.1

10

10.3

Total production mmboe (net)

8 6 4 2 0 04 Oil & liquids Gas

05

06

2002 Acquired Enron Oil and Gas India Limited and thereby a 30% participating interest in Panna/Mukta and Tapti fields 2004 Government approval for US$200 million Panna development plan 2005 Government approval for US$492 million mid Tapti development plan BG Group has emerged as a key private sector player within the gas industry in India, with a significant presence in the E&P and T&D segments. BG Group is seeking to play a greater role in India’s growing natural gas sector by developing its upstream position through licensing rounds and acquisitions. BG Group is also actively contributing to the developing regulatory debate on the further expansion of downstream markets and is interested in exploring further opportunities in each element of the gas chain. UPSTREAM In February 2002, BG Group completed the US$350 million acquisition of Enron Oil and Gas India Limited, gaining a 30% participating interest in the Tapti gas field and the Panna/Mukta oil and gas fields. The transaction significantly enhanced BG Group’s position as a leading player in the large and rapidly growing Indian energy sector. In 2006, the combined fields produced around 35.5 mmboe (gross) – representing approximately 8% of India’s total production. Gas production at the Panna/Mukta and Tapti (PMT) fields has increased by around 40% since the acquisition in 2002. BG Group is working with its partners and the government to progress expansion projects that are expected to increase overall production by 60% between 2006 and 2009. The increased production will be sold into the domestic market. The fourth wellhead platform on the south Tapti field came onstream in 2006 to help maintain a 250 mmscfd production rate. The PMT partners are working towards bringing the mid Tapti BG Group Data Book 2007

ASIA PACIFIC

Mahanagar Gas

ARABIAN SEA

1995 Mahanagar Gas Ltd (MGL) formed

Asia Pacific 20

India continued Sharing Contract (PSC) with the Government of India giving BG Group 45% interest in exploration block KG-OSN2004/1 in the Krishna Godavari Basin. The shallow water block, which covers an area of approximately 1 131 square kilometres, is located in the Krishna Godavari Basin off the east coast of India. ONGC holds the remaining 55% interest and operatorship of the block.

Partners Panna/Mukta and Tapti Fields (%)

BG Group ( joint operator) ONGC ( joint operator) Reliance Industries ( joint operator)

30 40 30

Partners block KG-OSN-2004/1 (%)

BG Group ONGC (operator)

45 55

field onstream during late 2007 to raise gas production to 450 mmscfd. The Panna infill programme which involved drilling 26 wells, was successfully completed in early 2006 and is expected to increase recovery by around 50 mmbbl and 200 bcf gas. As a part of the first phase of the approved Expanded Plan of Development (EPOD) for Panna, two wellhead platforms have been installed and development wells are being drilled. First production from EPOD was achieved on 6 February 2007. The EPOD for Panna also involves the drilling of 11 wells at a cost of US$140 million. Implementation is expected to result in gross incremental reserves of around 18 mmbbls oil and 74 bcf gas. Following government approval in 2004, the PMT partners began selling gas directly into the domestic market, seen as an important step forward in the liberalisation of India’s gas supply. BG Group was successful in the 2006 NELP VI licensing round. On 2 March 2007, BG Group and ONGC signed a Production

BG Group Data Book 2007

DOWNSTREAM Gujarat Gas Company Limited (GGCL) BG Group has a 65.12% controlling stake in GGCL, India’s largest private natural gas distribution company, supplying approximately 3.5 mmscmd. GGCL currently has more than 200 000 domestic, commercial and industrial customers, and serves more than 48 000 Compressed Natural Gas (CNG) users. The company has been part of the BG Group portfolio since 1997. The remaining 34.88% is publicly owned. In 2006, GGCL recorded another year of substantial growth in gas sales and in the CNG sector. During the year, more than 18 000 vehicles were converted to run on this cleaner burning fuel and GGCL added eight CNG stations to its network in Surat while upgrading one existing outlet. Sales of CNG for the year amounted to approximately 32 million kilograms. Industrial take-up of gas continued to be firm with more than 120 new customers signing up during the year. The retail sector saw particularly strong growth, with new contracts accounting for more than 500 000 scmd of additional gas. This included more than 48 MW of Combined Heat and Power (CHP) load. Growth in domestic demand also continued. The volume of gas sold increased by 34% from 811 mmscm to 1 088 mmscm. Investment to enlarge and upgrade GGCL’s pipeline network and associated infrastructure continued throughout 2006. Mahanagar Gas Ltd (MGL) MGL is based in India’s commercial capital, Mumbai. It is India’s largest city gas distribution company in terms of size of customer base. At present, there are 127 CNG outlets, with 627 dispensing points in Mumbai, Thane and MiraBhayander. MGL owns and controls almost 2 300 kilometres of pipeline and is extending its network beyond Mumbai into the neighbouring cities of Thane, Mira-Bhayander and Navi Mumbai. BG Group and GAIL (India) each have a 49.75% stake in the company, with the balance held by the Government of Maharashtra.

Currently, MGL supplies natural gas to more than 262 000 homes and 868 small commercial and industrial establishments in Mumbai. In 2006, MGL increased gas sold to 491 mmscm, an increase of nearly 10% on the previous year. Further expansion of the pipeline network to neighbouring towns is scheduled for completion by 2008.

Asia Pacific

China, Malaysia and Singapore

21

China

Key to operations Gas

BG Groupoperated

BG Group entered China in June 2006 following the signing of two PSCs with CNOOC (China National Offshore Oil Corp) covering deep water Blocks 64/11 and 53/16 and a Geophysical Survey Agreement (GSA) for Block 41/06, offshore China.

Oil Gas pipeline Oil pipeline

Pipeline – proposed or under construction

0

CHINA

250km

GUANGZHOU

MACAO

HONG KONG

HAIKOU

YANGPU DANZHOU DONGFANG TERMINAL

41/06

DONGFANG

SANYA

53/16 Pearl River Mouth Basin

Qiongdongnan Basin

The blocks, covering a total of approximately 25 800 square kilometres, are largely unexplored and, should commercial discoveries be made, are well placed to supply the high-growth markets of southern China.

MALAYSIA KUALA LUMPUR

Malaysia

Genting Sanyen Power

SINGAPORE

BORNEO SUMATRA

INDONESIA

INDIAN OCEAN 0

The exploration programmes for the PSC blocks will be carried out in three phases and involve the acquisition of 2D and 3D seismic and the drilling of exploration wells on each block. The GSA involves the acquisition and processing of 2D seismic. A 2D seismic programme in each of the three blocks commenced in 2007.

BG Group has a downstream interest in one of the country’s main power stations, Genting Sanyen Power, located south of the capital, Kuala Lumpur. Genting Sanyen Power BG Group was co-developer of this 760 MW combined cycle gas-fired power station and retains a 20% interest. Mastika Lengenda (a wholly owned subsidiary of Genting Group) owns 60% and Worldwide Holdings Bhd owns 20%. The total investment for the project was £400 million. Located in Kuala Langat, 70 kilometres south of Kuala Lumpur, Genting Sanyen began operations in 1996 and has a 21 year contract to sell power to Tenaga Nasional Berhad, the Malaysian national power company.

500km

Singapore BG Group’s Asia Pacific headquarters are located in Singapore, providing leadership and expertise in the fields of legal, finance, tax, exploration, LNG marketing and business development in support of projects and investments in the region.

BG Group Data Book 2007

ASIA PACIFIC

64/11

BG Group is the operator of the blocks and has a 100% interest during the exploration phase. In the event of a commercial discovery, CNOOC has the right to take an interest of up to 51% in the newly discovered field. Under the terms of the GSA, upon completion of the mandated work programme, BG Group has an exclusive option to enter into a PSC for Block 41/06.

Asia Pacific 22

Philippines entered full operation in August 2000. The project was completed below the budgeted £556 million.

Key to operations

LUZON

Gas pipeline Gas

MANILA

Oil 0

PHILIPPINE SEA

100km

Santa Rita/San Lorenzo

BATANGAS

SOUTH CHINA SEA

FGPC sells electricity to the Manila Electric Company (Meralco) under a power purchase agreement (PPA) that is effective until 2025.

MINDORO MALAMPAYA FIELDS

PANAY SULU SEA

PALAWAN

Key dates

Shareholders Santa Rita (%)

1995 Signed Power Purchasing Agreement (PPA) with Meralco for Santa Rita power station 1999 Signed PPA with Meralco for San Lorenzo power station 2002 Conversion of Santa Rita to natural gas San Lorenzo completed and commercial operation commenced BG Group First Generation Holdings Corporation

40 60

Shareholders San Lorenzo (%)

BG Group Unified Holdings Corporation

BG Group Data Book 2007

40 60

Siemens AG was the main contractor for the plant’s EPC contract and operates the plant on behalf of FGPC. Gas and condensate purchase agreements were signed in 1997 and, on 1 January 2002, the plant switched to natural gas operations when gas became available from the Shell/Chevron/PNOC Malampaya field.

BG Group is focused on the downstream sector of the gas chain, with interests in two gas-fired power generation plants, Santa Rita and San Lorenzo, located on the island of Luzon, 80 kilometres south of Manila, which supply about 12% of the electricity demand for Luzon Island, including Manila. FIRST GAS HOLDINGS CORPORATION (FGHC) Santa Rita Power Station The Santa Rita power station is owned by First Gas Power Corporation (FGPC), a 100% subsidiary of FGHC, in which BG Group has a 40% interest. The remaining 60% of FGHC is owned by First Generation Holdings Corporation (First Generation), which is a subsidiary of First Philippines Holdings Corporation (FPHC). The Santa Rita 1 000 MW power plant

FIRST GAS POWER CORPORATION San Lorenzo Power Station BG Group, in partnership with Unified Holdings Corporation, a 100% subsidiary of First Generation, developed, financed and constructed the San Lorenzo power plant. BG Group owns a 40% interest and Unified Holdings Corporation owns the remaining 60% interest in FGP Corp, the San Lorenzo project company. The San Lorenzo plant is located adjacent to the Santa Rita power plant and has a capacity of approximately 500 MW. Siemens AG operates the plant. The construction of the project was completed within the £303 million budget. Gas and condensate purchase agreements were executed similar to those for the Santa Rita project. San Lorenzo entered full commercial operation in October 2002, selling power to Meralco under a PPA valid until 2027. TRANSMISSION AND DISTRIBUTION In January 2001, FGHC was granted a 25 year franchise to install, own, operate and maintain a natural gas transmission and distribution pipeline business serving Luzon Island, including metropolitan Manila.

Asia Pacific

Thailand

23

New information • Three successful exploration wells drilled – Ton Chan IX, Ton Rang 2X and Ton Chan 2X

THAILAND BANGKOK

Key dates

RATCHABURI

RAYONG

CAMBODIA

1993 Bongkot came onstream

MYANMAR

2001 Memorandum of Understanding (MoU) between Thailand and Cambodia for a Joint Development Area

Block 7 Block 8 Block 9

Key to operations

0

BG Group’s investment in Thailand is concentrated on upstream activities, including an interest in the large offshore Bongkot field, which supplies approximately 20% of the country’s gas demand.

GULF OF THAILAND

Bongkot

BG Groupoperated block

BONGKOT GAS FIELD BG Group has a 22.22% interest in the Bongkot field, in the Gulf of Thailand, which came onstream in 1993. The field is operated by PTT Exploration and Production (PTTEP). The current daily contracted quantity has risen to 550 mmscfd (from an initial 150 mmscfd) through a phased development plan. The Bongkot field development currently consists of a central complex for gas gathering, processing, export and accommodation; a floating condensate storage and offloading (FSO) vessel; and 17 wellhead platforms, 13 of which are remote from the central complex.

BG Group non-operated block 200km

Thailand: BG Group 3 year production

Partners Bongkot (%)

9.8

10

9.3

9.4

Total production mmboe (net)

8 6 4 2 0 04 Oil & liquids Gas

05

06

BG Group PTTEP (operator) Total

22.22 44.45 33.33

In October 2006, the Group drilled the first exploration well in the Bongkot concession for eight years. Ton Chan IX encountered 143 metres of gas bearing sands. This was followed by two further successful exploration wells, Ton Rang 2X and Ton Chan 2X. Work is ongoing for additional phases of Bongkot field development, including Bongkot South, each of which are designed to extend the life of the field beyond the next decade. EXPLORATION BG Group is the operator (BG Group 50%) of Blocks 7, 8 and 9 in the Gulf of Thailand, in an area subject to overlapping claims by Thailand and Cambodia. In 2001, a MoU was signed by the Governments of Thailand and Cambodia aimed at concluding an agreement for the exploration and development of hydrocarbons in the overlapping claims area. A Joint Technical Committee is working to agree a mutually acceptable basis for resolution. BG Group Data Book 2007

ASIA PACIFIC

Gas pipeline

Block 9A

KHANOM

ANDAMAN SEA

Gas

1990 Entered a Participation and Operating Agreement (POA) with partners

Asia Pacific 24

Oman BG Group holds a 100% interest in, and operatorship of, Block 60 onshore Oman, following the signature of an Exploration and Production Sharing Agreement (EPSA) with the Government of the Sultanate of Oman on 30 April 2006.

IRAN

GULF OF OMAN UNITED ARAB EMIRATES

The block, which covers almost 1 500 square kilometres, contains the Abu Butabul gas and condensate discovery which was made in 1998. In addition to this discovery, there are other exploration prospects within the block.

MUSCAT

SAUDI ARABIA

Block 60

OMAN

Following ratification of the EPSA by His Majesty Sultan Qaboos in May 2006, BG Group established an office in Muscat to both deliver the Block 60 work programme and to act as a regional base to assess future opportunities in Oman and other states in the region.

ARABIAN SEA

Key to operations

YEMEN

Gas

Oil pipeline

Oil

BG Groupoperated block

Gas pipeline 0

200km

Key dates 2006 Signed an Exploration and Production Sharing Agreement for Block 60 2007 Seismic data acquired over 1 000 square kilometres of Block 60

BG Group Data Book 2007

Between January and August 2007, BG Group acquired seismic data over 1 000 square kilometres of Block 60 as part of the appraisal of the Abu Butabul structure. BG Group expects to drill the first appraisal well in fourth quarter 2007. This will be the first of at least five such wells. The Block 60 project marks BG Group’s entry into the natural gas sector in Oman, with the intention of appraising and commercialising potential reserves for supply into the domestic market.

Mediterranean Basin and Africa

Egypt

25

Key to operations MEDITERRANEAN SEA

Gas

Oil pipeline

Gas pipeline

BG Groupoperated block

0

North Sidi Kerir Deep

100km

BG Group’s activities in Egypt span the gas chain from exploration, through development and production, to downstream projects in LNG. BG Group’s business in Egypt comprises:

West Delta Deep Marine Simian Sienna Solar Silva

Scarab Saffron

Mina-1

Sapphire

• operatorship of two gas-producing areas offshore the Nile Delta:

Serpent

Saurus

Sienna-Up

Sequoia

Rashid North Ext.

Rosetta El Burg El Manzala

ALEXANDRIA

IDKU

DAMIETTA LNG

Egyptian LNG Trains 1 & 2

Egypt is a core part of BG Group’s global portfolio and a cornerstone of its Atlantic Basin LNG strategy. BG Group is also one of the largest investors in Egypt’s natural gas business.

PORT SAID

EGYPT

– the Rosetta Concession (BG Group 80%, Edison 20%); and – the West Delta Deep Marine (WDDM) Concession (BG Group 50%, PETRONAS 50%); • operatorship of three other concessions offshore the Nile Delta: – El Manzala Offshore (BG Group 100%); – El Burg Offshore (BG Group 70%, PETRONAS 30%); and – North Sidi Kerir Deep (BG Group 50%, PETRONAS 50%);

CAIRO

New information

Egypt: BG Group 3 year production Total production mmboe (net) 62.4 35.2

60

• Divested interest in Nile Valley Gas Company

Key dates

14.2

40 20

• Exploration well planned in early 2008 for El Manzala licence

1995 Rosetta and WDDM concessions awarded

0 04

05

06

Oil & liquids Gas

2001 Egyptian LNG Export Agreement signed Rosetta onstream 2002 Egyptian LNG Train 1 EPC and SPA signed 2003 Scarab Saffron onstream

Partners Rosetta Concession (%)

Egyptian LNG Train 2 EPC and SPA signed 2004 Acquired additional 40% in Rosetta concession 2005 Damietta and Egyptian LNG Train 1 and Train 2 exports began Simian, Sienna and Sapphire onstream El Burg and El Manzala concessions awarded BG Group (operator) Edison

80 20

2006 North Sidi Kerir Deep concession signed Divested interest in Nile Valley Gas Company

(i) A train is a processing facility that converts dry natural gas to a liquefied state by cooling the gas to minus 160 degrees centigrade, allowing it to be transported by specially configured tanker ships.

• production of gas from the Scarab Saffron fields in WDDM to the Egyptian domestic market with a current maximum delivery obligation of 775 mmscfd, of which approximately 225 mmscfd (reducing to approximately 150 mmscfd from 2009) is processed through Damietta LNG (Union Fenosa JV Co SEGAS). BG Group and Scarab Saffron partner PETRONAS lift the equivalent volume of LNG from the Damietta plant; • production of gas from the Simian, Sienna and Sapphire fields in WDDM supplying Egyptian LNG Train 1 at 565 mmscfd and Egyptian LNG Train 2 at 565 mmscfd; and • major shareholdings in the Egyptian LNG project (Train 1 35.5% and Train 2 38%)(i). BG Group undertakes upstream development and production activities in Egypt through joint operating companies. In the case of Rosetta, this is the Rashid Petroleum Company (Rashpetco) in which BG Group has a 40% shareholding, and in the case of WDDM, this is Burullus Gas Company (Burullus) in which BG Group has a 25% shareholding. These operating companies are 50% owned by the Egyptian state-owned oil company Egyptian General Petroleum Corporation (EGPC). BG Group and its BG Group Data Book 2007

MEDITERRANEAN BASIN AND AFRICA

80

• 3D seismic acquired over El Burg, El Manzala and North Sidi Kerir Deep licences

• production of gas from the Rosetta Concession supplying the Egyptian domestic market at a DCQ of 345 mmscfd;

Mediterranean Basin and Africa 26

Egypt continued Partners Rashid Petroleum Company (%)

partners in each concession hold the remaining 50%. EXPLORATION West Delta Deep Marine Concession BG Group and partners have drilled 19 successful exploration and appraisal wells in WDDM since 1997 and this has resulted in the discovery of 11 gas fields: Scarab Saffron; Simian; Sienna; Sapphire; Serpent; Saurus; Sequoia; Solar; Sienna Up; Mina and Silva.

BG Group EGPC Edison

40 50 10

El Manzala Offshore and El Burg Offshore Concessions In July 2005, BG Group signed El Burg and El Manzala concession agreements for exploration of gas and oil in the Mediterranean Sea with the Egyptian Natural Gas Holding Company (EGAS). In 2006, 3D seismic was acquired on El Manzala and exploration drilling is planned for early 2008.

Partners WDDM Concession (%)

BG Group (operator) PETRONAS

50 50

Partners Burullus Gas Company (%)

BG Group EGPC PETRONAS

25 50 25

Partners El Burg Concession (%)

BG Group (operator) PETRONAS

BG Group Data Book 2007

In 2006, BG Group and partner PETRONAS relinquished their exploration acreage in WDDM and, in 2007, secured additional development leases on the concession.

A large, shallow water 3D seismic survey was completed on the adjacent El Burg concession in 2006. BG Group expects to spud the first well on this block in 2008. North Sidi Kerir Deep Concession The North Sidi Kerir Deep concession, signed in July 2006, covers 1 949 square kilometres in water depths of approximately 1 000 – 2 000 metres, adjacent to WDDM. BG Group acquired 3D seismic in 2006 and expects to drill the first well in 2009. UPSTREAM DEVELOPMENT AND PRODUCTION Rosetta Rosetta started production in 2001 and supplies Egypt’s domestic network. In 2004, BG Group acquired a further 40% interest in Rosetta. BG Group sanctioned the Rosetta Phase 3 field development plan in second quarter 2006 and expects to deliver gas from the first project wells in late 2007. Scarab Saffron Scarab Saffron started production in 2003 and supplies gas to the domestic market and to Damietta LNG. Currently, the maximum delivery obligation under the domestic GSA is 775 mmscfd.

70 30

Under an agreement signed with EGAS in 2004, gas has been de-dedicated for five years from the domestic GSA so that, since February 2005, approximately 225 mmscfd of this gas has been processed through the Damietta LNG plant for a tolling fee. This will reduce to approximately 150 mmscfd from 2009.

BG Group and its WDDM partner PETRONAS lift the corresponding volume (1.4 mtpa) of LNG. BG Group lifted its first cargo from Damietta in March 2005. Scarab Saffron is the first deep water subsea development in Egypt. These facilities consist of eight sub-sea wells connected to a sub-sea manifold, in turn connected by 24-inch diameter and 36-inch diameter pipelines to an onshore processing terminal. Electrical and hydraulic lines connect the wells to the onshore control room. The fields are located approximately 90 kilometres from the shore and in water depths of more than 700 metres. Simian, Sienna and Sapphire The Simian and Sienna fields produced first gas on 15 April 2005, for supply to Egyptian LNG Train 1 at Idku. The Sapphire field produced first gas on 8 September 2005, for supply to Egyptian LNG Train 2. The Simian, Sienna and Sapphire fields are located in WDDM approximately 120 kilometres offshore Idku, near Alexandria, in the Mediterranean Sea. The facilities consist of 16 sub-sea wells tied into the existing WDDM gas gathering network and a shallow water control platform. The onshore processing facilities form part of the Idku Gas Hub where the Egyptian LNG facilities are located. In 2002, the WDDM concession agreement was amended to allow gas exports from the concession. This followed the 2001 signing of a LNG export agreement between BG Group, its partners and EGPC. In second quarter 2006, BG Group sanctioned the Phase 4 development of WDDM and expects to deliver gas from the project in early 2008. DOWNSTREAM PROJECTS Egyptian LNG BG Group and partner supply Train 1 of Egyptian LNG with 565 mmscfd gas and supply Train 2 with 565 mmscfd gas from the Simian, Sienna and Sapphire fields in WDDM. The 3.6 mtpa output from Train 1 has been sold to Gaz de France under a 20 year SPA. The first LNG cargo from Train 1 was lifted in May 2005, some three months ahead of schedule. The 3.6 mtpa output of Train 2 has been sold to BG Group under a 20 year agreement. BG Group may deliver this output to its capacity at Lake Charles in the USA or divert to other markets, as part of its flexible portfolio approach. The first LNG cargo from Egyptian LNG Train 2 was lifted in September 2005, some nine months ahead of schedule.

27

The Egyptian LNG facilities, which include the common facilities such as storage tanks, loading jetty and utilities, are located in their own tax free zone at Idku. The plant produces a total of 7.2 mtpa LNG using Phillips liquefaction technology. The total project cost of Trains 1 and 2 was around US$1.9 billion. Project financing of US$949 million was secured for Train 1 in 2004 and US$880 million was secured for Train 2 in 2005. The latter includes US$320 million to repay the Train 1 Company for Train 2’s share of the common facilities.

Nile Valley Gas Company (NVGC) BG Group sold its interest in NVGC on 13 November 2006.

Shareholders ELNG Holding, Opco and Train 1 Co (%)

BG Group PETRONAS EGPC EGAS Gaz de France

There is sufficient space at the Idku site for a further four LNG trains. The commercial structure of Egyptian LNG has been designed to allow future expansion without the need to involve all existing partners, and it is possible that third parties could supply gas to future Egyptian LNG trains.

35.5 35.5 12.0 12.0 5.0

Shareholders Train 2 Co (%)

BG Group PETRONAS EGPC EGAS

38 38 12 12

Simian, Sienna and Sapphire: integrated upstream and downstream GAS SUPPLY

Start date 2005

565 mmscfd – Simian and Sienna

Gas

BG Group

50%

Start date 2005

565 mmscfd – Sapphire

50%

UPSTREAM

Train 1 – 3.6 mtpa Tolling plant BG Group PETRONAS EGPC EGAS Gaz de France

35.5% 35.5% 12% 12% 5%

LNG

Gaz de France

100%

Train 2 – 3.6 mtpa Tolling plant

Gas

BG Group

LNG PURCHASE

LIQUEFACTION OUTPUT

BG Group PETRONAS EGPC EGAS

LIQUEFACTION OUTPUT

38% 38% 12% 12%

LNG

BG Group

100%

DOWNSTREAM

BG Group Data Book 2007

MEDITERRANEAN BASIN AND AFRICA

Egyptian LNG Company owns both the Egyptian LNG site and common facilities. Its sister company, Egyptian Operating Company for Natural Gas Liquefaction Projects (Opco) (BG Group 35.5%), undertakes the operation of all trains. El Behera Natural Gas Liquefaction Company (Train 1 Co) (BG Group 35.5%) owns Train 1. The ownership of further train companies will differ, for example, Idku Natural Gas Liquefaction Company (Train 2 Co) (BG Group 38%) has a different ownership structure from Train 1 Co.

Mediterranean Basin and Africa 28

Israel and areas of Palestinian Authority Key to operations BG Group-operated block

LEBANON

Gas 0

50km

ISRAEL Med Yavne lease BG Group is operator of the Med Yavne lease, which was reduced to an area of 52.3 square kilometres around the Or gas discovery made in 1999.

MEDITERRANEAN SEA

Offshore Gaza Or Gaza Marine

ISRAEL

Med Yavne

GAZA EGYPT

Key dates 1999 Acquired Med licences and Offshore Gaza licence Or gas discovery 2000 3D seismic data shot over Offshore Gaza and Med licences Gaza Marine gas discovery 2002 Additional 2D seismic shot over Offshore Gaza licence 2005 Relinquished Gal licences

BG Group Data Book 2007

BG Group has been active in Israel and areas of Palestinian Authority since 1996, with current activities focused upon the successful commercialisation of its offshore gas discoveries.

AREAS OF PALESTINIAN AUTHORITY Offshore Gaza BG Group is operator of an exploration licence covering the entire marine area offshore the Gaza Strip. Following acquisition of over 1 000 square kilometres of 3D seismic data, BG Group drilled two successful wells in second half 2000 (Gaza Marine-1 and Gaza Marine-2). Reserves are estimated to be around 1 tcf. In 2001, a technical review recommended a sub-sea development and pipeline to an onshore processing terminal. In 2002, an outline Development Plan was approved by the Palestinian Authority. During late 2002, BG Group acquired an additional 925 kilometres of 2D seismic data over the area between the existing discoveries and the shore. BG Group holds 90% equity in the licence, which would be reduced to 60% if the Consolidated Contractors Company (its current 10% partner in the licence) and the Palestine Investment Fund, exercise their options at development sanction. The Group is evaluating options for commercialising the gas. As Israel’s need for gas grows, negotiations are ongoing with the Government of Israel to deliver the gas into the Israeli domestic market. BG Group also continues to review the option of an additional train at Egyptian LNG, potentially combining Gaza gas with other supply options.

Mediterranean Basin and Africa

Algeria, Libya and Madagascar

29

ALGERIA BG Group entered Algeria through an agreement with Gulf Keystone in June 2006 to acquire an interest in the Hassi Ba Hamou PSC. Following completion of the transaction in December 2006, BG Group has a 36.75% interest in, and is operator of, the block. Gulf Keystone has a 38.25% interest and the state oil and gas company, Sonatrach, has a 25% interest.

ALGIERS

TUNISIA

MOROCCO Hassi Ba Hamou

Key to operations Gas

Oil pipeline

Oil

BG Groupoperated block

LIBYA

ALGERIA

Gas pipeline

0

400km

Key to operations

TUNISIA

TRIPOLI

Gas

Oil pipeline

Oil

BG Groupoperated block

Gas and Oil/ Condensate Gas pipeline

BG Group non-operated block

0

100km

EGYPT

Area 123 Block 2 Area 123 Block 1

ALGERIA

LIBYA In October 2005, BG Group was successful in Libya’s second licensing round, acquiring a mix of largely unexplored acreage in both an established basin and a frontier area. BG Group was awarded a 100% interest in, and operatorship of, Area 123 (Blocks 1 and 2) covering 4 900 square kilometres in Libya’s prolific onshore Sirt Basin. 3D seismic operations commenced in first quarter 2007 and BG Group expects to drill its first well in 2008. BG Group was awarded a 50% nonoperated interest in Area 171, containing Blocks 1, 2, 3 and 4, covering 11 300 square kilometres onshore in the frontier Kufra Basin. 2D seismic operations commenced in first quarter 2007 and the first well is expected to spud in 2008.

Area 171 Blocks 1,2,3,4

TANZANIA SEYCHELLES

In May 2007, a Joint Announcement of Co-operation was signed between the NOC and BG Group, to study optimum solutions for supplying natural gas to both domestic and export markets.

Majunga Offshore Profond

MOZAMBIQUE

BG Group also signed a MoU with Sonatrach in March 2006, which provides a non-exclusive framework for discussions targeting the joint development of integrated gas chain projects.

MADAGASCAR ANTANANARIVO

Key to operations Gas pipeline Oil pipeline BG Group non-operated block 0

100km

MADAGASCAR In June 2006, BG Group acquired a 30% interest in the Majunga Offshore Profond exploration block in Madagascar under a farm-in agreement with Vanco. BG Group’s partners are ExxonMobil (operator, 50%), SK Energy (10%) and PVEP Corp (10%). The block covers around 15 160 square kilometres in deep water (200-3 000 metres) off north-west Madagascar. Believed to be oil prone, it forms part of a largely unexplored frontier basin that is believed to have significant potential. BG Group Data Book 2007

MEDITERRANEAN BASIN AND AFRICA

LIBYA

The Hassi Ba Hamou Perimeter, in central Algeria, consists of the Hassi Ba Hamou gas discovery and five blocks (317b, 322b3, 347b, 348 and 349b), covering approximately 18 380 square kilometres. Acquisition of 2D and 3D seismic began in early 2007 and six wells are expected to be drilled prior to the expiry of the initial prospecting phase in September 2008.

Mediterranean Basin and Africa 30

Nigeria

IBADAN ABEOKUTA

AKURE

PORTO NOVO LAGOS

OKLNG

NIGERIA

BENIN CITY

OPL 332

PORT HARCOURT

ESCRAVOS

CALABAR

Nigerian licensing round. The licence is located in deep water (200 – 1 000 metres) close to the giant Bonga field, offshore the western Niger Delta, approximately 250 kilometres south-east of Lagos. BG Group is the operator with a 66% interest, along with partners Sahara (24%) and Equinox (10%). The block contains an existing discovery, Boi. Exploration and appraisal drilling is targeted for 2008/09. BG Group continues to evaluate further upstream opportunities in Nigeria.

NLNG

OPL 286-DO BRASS LNG

LUBA

Key to operations Gas

Oil pipeline

Oil

BG Groupoperated block

Gas pipeline 0

100km

New information • Signed PSC and associated Downstream MoU for OPL 286-DO • Seismic acquisition completed on Block OPL 332 • Olokola LNG (OKLNG) Shareholders Agreement (SHA) and Free Trade Zone agreement signed • SPA signed with Nigeria LNG Train 7 for 2.25 mtpa LNG for 20 years

Key dates 2006 PSC signed for OPL 332 in January Contracted LNG deliveries from Nigeria LNG (NLNG) Trains 4/5 began MoU to buy LNG from Brass LNG signed in January OKLNG Joint Venture PDA signed in February Awarded licence OPL 286-DO following the licensing round in May 2007 Sale and Purchase agreement signed for NLNG Train 7 PSC and associated Downstream MoU signed for OPL 286-DO OKLNG SHA signed

BG Group Data Book 2007

BG Group commenced business development activities in Nigeria in mid-2004. Nigeria offers the potential of an excellent strategic fit with BG Group’s gas chain capability and Atlantic Basin position in light of its hydrocarbon potential. UPSTREAM In January 2006, BG Group signed a PSC for Block OPL 332 with the Nigerian National Petroleum Corporation (NNPC), which resulted in BG Group acquiring a 45% interest in, and operatorship of, the deep water block. The PSC followed a farm-in agreement with Sahara Energy E&P Limited, which now retains a 35% interest. Other partners with an interest in the Block are the Nigeria Petroleum Development Company with 10% and Seven Energy Nigeria Limited with 10%. OPL 332 is located in up to 1 000 metres of water, approximately 100 kilometres south-east of Lagos. The first phase of the two-part work programme on OPL 332 began in 2006. Acquisition of 3D seismic on the Block was completed in January 2007 and the drilling of an exploration well is targeted for 2008/09. In March 2007, BG Group signed a PSC and associated downstream MoU for Block OPL 286-DO with NNPC. BG Group, together with Sahara, was awarded licence OPL 286-DO in the May 2006

LNG BG Group and its partners are developing a liquefaction plant at Olokola (OKLNG) on the south-western coast of Nigeria. In March 2007, the partners signed the Shareholders’ Agreement (SHA) which replaces the previous Project Development Agreement. The SHA signed between NNPC, Shell, Chevron and BG Group, which includes the development of the launch project and any future expansions, sets out the governance within the project company and shareholders’ rights to supply gas and offtake LNG. In April 2007, a groundbreaking ceremony lead by the President of Nigeria took place at the site in Ogun State at which the Free Trade Zone agreement was signed. The proposed project will comprise four LNG trains of approximately 5.5 mtpa each, with development envisaged in two phases each of 11 mtpa capacity. BG Group has a 13.5% share in the project. All shareholders will have the right to lift their equity share of LNG. In February 2007, BG Group signed a SPA with Nigeria LNG (NLNG) for the acquisition of 2.25 mtpa of LNG for a 20 year term that will be produced by NLNG’s proposed Train 7 project in Finima, Bonny Island. First deliveries to Lake Charles in the USA are expected to commence in 2012. In 2006, BG Group announced a MoU with Brass LNG for the acquisition of LNG. Volumes are expected to be 1.67 mtpa LNG. The proposed agreement will be for a 20 year term, with initial deliveries expected to commence during 2011. These purchases complement the earlier signing of a 20 year SPA for 2.3 mtpa LNG from Nigeria LNG Trains 4 and 5 located on Bonny Island. Deliveries under this agreement commenced in January 2006.

Mediterranean Basin and Africa

Tunisia

31

Key to operations Gas

Oil pipeline

Oil

BG Groupoperated block

BIZERTE

Gas pipeline 0

100km

TUNIS

TUNISIA SOUSSE

MEDITERRANEAN SEA ME SFAX

Hannibal

Amilcar LA SKHIRA

GULF OF GABES

Miskar Hasdrubal Ulysse A Ulysse B

Tunisia: BG Group 3 year production

New information

12.4

Key dates

12.5

15

12.3

• Hasdrubal construction commenced in January 2007

12

1989 Acquired Tenneco assets

9

1996 Miskar field first production

6

2006 Hasdrubal development plan approved

3 0 04 Oil & liquids Gas

05

06

BG Group is the largest producer of gas in Tunisia, supplying approximately 50% of the domestic gas demand from the Miskar field. In addition, BG Group holds two exploration permits in the Gulf of Gabes with a combined surface area of 4 088 square kilometres. AMILCAR PERMIT BG Group is operator and joint permit holder with Entreprise Tunisienne d’Activités Pétrolières (ETAP), the Tunisian state-owned company, of the Amilcar exploration permit, offshore Sfax in the Gulf of Gabes. In 2006, BG Group was granted a new extension to this permit, which now expires in December 2009. BG Group plans to drill two additional wells in 2007/2008 to further prove reserves in the Amilcar permit. Within this permit are the Miskar concession (BG Group 100%) and the Hasdrubal concession (BG Group 50% and operator, ETAP 50%).

MISKAR INFILL WELLS BG Group is in the process of drilling six wells as part of the Miskar infill drilling campaign. The wells will be drilled in phases, with two wells expected to be completed in each of 2007, 2008 and 2009. These wells will further extend the field production plateau. Related projects are underway to upgrade the production facilities to process varying compositions of gas and to de-bottleneck the facilities. CONDENSATE PIPELINE A 60 kilometre condensate pipeline is planned to be commissioned in third quarter 2007. This will improve safety by removing the need to transport condensate by road. HASDRUBAL DEVELOPMENT BG Group drilled its first appraisal well, Hasdrubal-3, in 1997. A further appraisal well, Hasdrubal-4, was drilled in 1998. During 2002, BG Group drilled a further appraisal well, Hasdrubal-SW1, which tested light oil and confirmed the extension of the Hasdrubal field to the south-west. The Hasdrubal development plan was approved by the Tunisian government in June 2006. All major contracts have now been awarded and construction continues. First gas from this joint project (BG Group 50%, ETAP 50%) is planned for first half 2009. Hasdrubal is a US$1.2 billion project and once production commences, BG Group will be the largest producer of gas, LPG and liquids in Tunisia. ULYSSE PERMIT BG Group is operator and joint permit holder (with ETAP) of the Ulysse exploration permit, offshore Sfax in the Gulf of Gabes. BG Group acquired an extension of approximately 900 square kilometres to the Ulysse permit in 2004. Two wells are required to be drilled by 2008.

BG Group Data Book 2007

MEDITERRANEAN BASIN AND AFRICA

Total production mmboe (net)

MISKAR GAS FIELD BG Group produced around 12.4 mmboe net of gas from its Miskar field during 2006, including fuel gas and condensate. Production from this concession commenced in 1996. Gas from the field is processed at the BG Group Hannibal plant, 21 kilometres south of Sfax, and sold into the Tunisian gas system. BG Group has a Miskar gas sales contract with the Tunisian state electricity and gas company, Société Tunisienne de l’Electricité et du Gaz (STEG), which gives BG Group the right to supply up to 230 mmscfd on a long-term basis. Offshore compression was commissioned in 2005 to maintain the production plateau of the field.

North America and the Caribbean and Global LNG

Canada and Alaska Canada

EL 444 EL 429/445

EL 432

BG Group’s Canadian exploration activities are focused in Alberta and British Columbia. BG Canada currently holds 75 253 net hectares in the Foothills and Deep West area of the Western Canadian Sedimentary Basin. Exploration activities are focused in the northern and central Foothills and the Wild River Basin. BG Canada also holds interests in 319 487 net hectares in the Northwest territories.

NORTHWEST TERRITORIES

YUKON TERRITORY

Northern Foothills

ALBERTA

BRITISH COLUMBIA

FORT ST JOHN

Central Foothills

Key to operations Gas

Deep West

BG Groupoperated block

Oil Gas pipeline

BG Group non-operated block

CALGARY

Oil pipeline 0

VANCOUVER

500km

Waterton

USA

ARCTIC OCEAN

PRUDHOE BAY

BEAUFORT SEA

ENS Contract Area Foothills Contract Area

CANADA

ALASKA

Key to operations Gas

BG Groupoperated block

Oil Gas pipeline

BG Group non-operated block

Oil pipeline 0

500km

TransAlaska Pipeline

Canada: BG Group 3 year production

3.5

3.3

Total production mmboe (net)

3.5 3.0

New information • Sold Bubbles, Ojay and Copton/Lynx assets in Canada for C$516 million • Acquired further acreage in the Northwest Territories

2.5

Key dates

2.0

2005 Awarded acreage in the Northwest Territories

1.5 1.0

2006 Entry into Alaska via acreage in eastern North Slope and foothills of North Slope

0.5 0 04 Oil & liquids Gas

BG Group Data Book 2007

05

In May 2005, BG Group acquired two licences (EL 429 and EL 432) in the Colville Lake area of the Mackenzie Valley, Northwest Territories, about 700 miles northwest of Yellowknife. BG Group has a 75% interest and is operator. BG Canada is preparing to acquire a 200 kilometre heliportable seismic programme in this area over summer 2007. In September 2005, BG Group acquired a 100% interest in a 1 280 hectare licence and a 50% interest in a 768 hectare licence in the Waterton area of southeast Alberta. In January 2006, BG Group acquired a 100% interest in a 18 000 hectare licence in the Robb Lake area of northeast British Columbia. In May 2007, BG Group acquired two further licences, EL 444 (BG Group 100%) and EL445 (BG Group 75% and operator) in the Colville Lake area of the Northwest Territories. On April 2 2007, BG Group sold its assets in the Bubbles, Ojay and Copton/Lynx areas of the Western Canadian Sedimentary Basin to Progress Energy Limited for C$516 million. The Group’s 50% interest in the producing asset in southwest Alberta, Waterton, was retained.

Alaska

ANCHORAGE

2.8

32

06

In January 2006, BG Group signed a Participation Agreement for a 33.33% interest in 2.1 million acres in the Foothills area of the Alaskan North Slope. Equal partners are Anardarko (operator) and Petro-Canada. Alaska’s North Slope has estimated discovered reserves in excess of 17 billion barrels of oil and 35 tcf of gas. In April 2006, BG Group signed a further Exploration Agreement to acquire a 40% interest in 208 000 acres of land along Alaska’s eastern North Slope (ENS). Partners are Anardarko with 50% (operator) and Arctic Slope Regional Corporation with 10%. The acreage is located on the coastal plain near the Prudhoe Bay field, which has produced over 10 billion barrels of oil. As of July 2007, BG Alaska has interests in over 3.1 million acres in the ENS and foothills of North Slope. Drilling or seismic activities are now being carried out in both of these areas.

North America and the Caribbean and Global LNG

Trinidad and Tobago

33

Key to operations Gas

Gas pipeline

Oil

BG Groupoperated block

0

100km

ATLANTIC OCEAN

TOBAGO

Poinsettia Chaconia NCMA Unit Area

Hibiscus Ixora

CARIBBEAN SEA

Petrotrin Refinery Pointe-a-Pierre

PORT OF SPAIN

ECMA

TRINIDAD D

GULF OFF PARIA

Starfish Block E

PHOENIX PARK

Central Block

Atlantic LNG POINT FORTIN

Block 5(a) Dolphin Deep Dolphin Block 6(b)

BEACHFIELD

Loran/ Manatee Block 6(d)

VENEZUELA

New information

Trinidad and Tobago: BG Group 3 year production

• Successful Baraka East-1 exploration well drilled in Central Block 22.6

Total production mmboe (net)

20

18.0

19.1

25

• Agreement signed for 220 mmscfd supply to National Gas Company (NGC) in May 2007

Key dates

15

1996 First Dolphin production

10

1999 Atlantic LNG Train 1 became operational

5 0 04 Oil & liquids Gas

05

06

2002 Atlantic LNG Train 2 start-up 2003 Atlantic LNG Train 3 start-up 2004 Acquisition of Central Block 2005 Manatee-1 discovery Atlantic LNG Train 4 start-up 2006 Dolphin Deep onstream

EAST COAST MARINE AREA (ECMA) The BG Group-operated Dolphin gas field, located 83 kilometres off the east coast of Trinidad in Block 6(b), commenced production in March 1996. The Dolphin field is contracted to supply 275 mmscfd gas to NGC under a 20 year supply contract. The ECMA also supplies 100 mmscfd to Atlantic Train 3 and 120 mmscfd to Atlantic Train 4. The gas is produced under a Combined Development Plan for the fields in Blocks 5(a), 6 and E fields. Reserves from the Dolphin Deep field are being produced through upgraded facilities on the Dolphin platform and a new gas receiving facility at Beachfield. The two Dolphin Deep wells were the first sub-sea completions in Trinidad and Tobago, and came onstream in July 2006. ECMA gas is being delivered to Atlantic LNG via two new pipelines – a new 95 kilometre 24-inch diameter offshore pipeline bringing ECMA gas from the Dolphin platform to shore at Beachfield, and NGC’s new 76 kilometre 56-inch diameter onshore Cross Island Pipeline (CIP) extending from Beachfield to Atlantic LNG at Point Fortin. Plans are now in place for further development of the Dolphin field to enable delivery of the 220 mmscfd of new supply covered under the recent agreement with NGC. In January 2005, BG Group and partner Chevron completed the Manatee-1 well in Block 6(d) in the ECMA, which indicated gross reserves of between 1.3 and 1.6 tcf. This was a significant gas discovery and demonstrated the extension of the Loran field from Venezuela into Block 6(d) in Trinidad and Tobago. In March 2007 the Governments of Venezuela and Trinidad and Tobago signed a Framework Unitisation Treaty for cross-border developments. BG Group and Chevron are evaluating future exploration drilling plans in their ECMA acreage which is held under several PSCs. BG Group Data Book 2007

NORTH AMERICA AND THE CARIBBEAN

2001 Hibiscus platform installed

BG Group has been operating in Trinidad and Tobago since 1989, and continues to reinforce its position as a major gas player in the country. BG Group currently supplies gas to the domestic market and to Atlantic LNG primarily for export to North America. In May 2007, BG Group signed an agreement to supply 220 mmscfd of natural gas to the Trinidad and Tobago NGC for up to 15 years. In March 2007, BG Group also signed a Memorandum of Understanding with the Government of Trinidad and Tobago to study the feasibility of LNG expansion in the country.

North America and the Caribbean and Global LNG 34

Trinidad and Tobago continued NORTH COAST MARINE AREA (NCMA) The BG Group-operated NCMA development, located 40 kilometres off the north coast of Trinidad, includes four gas fields: Hibiscus, Poinsettia, Chaconia and Ixora. In April 2000, a Unitisation Agreement was signed, and in December 2000 the Government of Trinidad and Tobago approved the development of the first three fields. These fields are being developed in up to four phases to supply gas to Atlantic LNG Trains 2, 3 and 4.

Partners Dolphin, Dolphin Deep and Starfish – ECMA (%)

BG Group (operator) Chevron

50 50

Partners Hibiscus – NCMA (%)

The Hibiscus platform was successfully installed in 2001, in a water depth of 150 metres, together with a 107 kilometre 24-inch diameter pipeline from NCMA to Atlantic LNG at Point Fortin. Debottlenecking in 2003 increased capacity of the pipeline to 30% above the original design. The Ixora prospect was drilled and successfully completed in 2003 as part of drilling operations on the Hibiscus and Chaconia fields.

BG Group (operator) Petrotrin Eni PetroCanada

45.88 19.50 17.31 17.31

Partners Central Block (%)

BG Group (operator) Petrotrin

BG Group Data Book 2007

65 35

The H-4 well was drilled and completed as the first sub-sea well on the north coast of Trinidad and was successfully brought on production in September 2006. Three additional infill sub-sea wells were drilled and successfully brought on production during December 2006 and January 2007 in Chaconia and Eastern Hibiscus as part of Phase 3b of the NCMA development. The next phase of activity in the NCMA includes the development of the Poinsettia field as part of Phase 3c, which includes building a new platform, drilling four wells from the platform and one subsea well. This is expected to be onstream at the end of 2008. A new 20-inch pipeline will connect the new platform to the existing Hibiscus Platform some 20 kilometres away. Deeper gas accumulations beneath the Poinsettia field were discovered by the Poinsettia-1a well in 2004. These discoveries are under evaluation and may require further appraisal prior to their inclusion in the NCMA development programme. In 2002, BG Group and its partners announced first gas production from the NCMA Hibiscus field into the newly commissioned Atlantic Train 2. NCMA is contracted to supply 240 mmscfd gas to Train 2 for up to 20 years, in addition to 125 mmscfd to Train 3 for the first two years, reducing thereafter to 45 mmscfd. Production into Train 3 started in 2003 and NCMA has consistently produced at rates 12% above the original DCQ for both Atlantic LNG Trains 2 and 3. NCMA started to supply gas to Atlantic LNG Train 4 in December 2005. The Train 4 supply contract is for approximately 80 mmscfd.

CENTRAL BLOCK BG Group holds a 65% interest and operatorship of this 111 square kilometre block. State-owned company Petrotrin holds the remaining 35% under an Exploration and Production Licence, which was renegotiated and signed in September 2006. The discoveries in the block include the currently producing Carapal Ridge field, as well as Baraka and Corosan. BG Group currently supplies 20 mmscfd gas and 500 bopd condensate to Petrotrin, for use in its refinery at Pointe-a-Pierre. Gas is transported via a 12 kilometre, 10-inch diameter pipeline that connects to the NGC network. Onshore and close to the Cross Island Pipeline, Central Block also presents a relatively low cost opportunity for supply to Atlantic LNG. A new gas plant with a capacity of 65 mmscfd is being constructed near the existing production site at Carapal Ridge. This increased capacity is expected to supply up to 45 mmscfd for BG Group’s capacity in Atlantic LNG Train 4 from September 2007. At the end of 2006, the Baraka East-1 exploration well indicated a rich gas with a high condensate to gas ratio of 60 to 1, significantly higher than the Carapal producing field. A new 3D seismic programme will be carried out in 2007, to be followed by exploration drilling. ATLANTIC LNG The Atlantic LNG Company of Trinidad and Tobago, in which BG Group is a shareholder, constructed a US$1 billion LNG plant at Point Fortin, south-west Trinidad which began operating in 1999. This first train produces 3.1 mtpa LNG which is sold to markets in the north-east United States, Puerto Rico and Spain. Train 2 commenced production in 2002 and Train 3 in 2003, with the additional two trains producing on average a total of 7 mtpa. Combined construction costs for Train 2/3 was US$1.1 billion. With the completion of the 5.2 mtpa Train 4 in December 2005, the total LNG production capacity of Atlantic LNG is more than 15 mtpa. Train 4 is one of the world’s largest liquefaction facilities, with 800 mmscfd gas supply of which BG Group and upstream partners supply 28.89%. The gross cost of Train 4 was US$1.2 billion. The LNG produced from gas supplied to Trains 2 and 3 by BG Group and its partners is sold to BG Gas Marketing (BGGM), a wholly owned BG Group subsidiary, following contract assignment by El Paso Merchant Energy under

35

NCMA, ECMA, Central Block and Atlantic LNG: integrated upstream and downstream

Start date 1999

c560 mmscfd

c560 mmscfd

Start date 2006

c520 mmscfd (non-BG supply)

Start date 2002

LIQUEFACTION OUTPUT

Start date 2003

GAS SUPPLY

Train 1 – 3.1 mtpa Merchant plant

Gas

BG Group

LNG 26%

Train 2 – 3.4 mtpa Tolling plant

Gas

BG Group

BG Group and upstream partners

Train 3 – 3.4 mtpa Tolling plant BG Group

BG Group and upstream partners

32.5%

Train 4 – 5.2 mtpa Tolling plant

Gas

BG Group

a long-term contract for import into the Elba Island LNG receiving terminal in Georgia, USA. LNG produced from the BG Group liquefaction capacity in Train 4 is sold free on board (FOB) under a long-term contract to BGGM for potential delivery into the US market via the Lake Charles import terminal in Louisiana. BG LNG Services (BGLS), a wholly owned subsidiary of BG Group, has an agreement to utilise 100% of the available capacity at Lake Charles (see page 36).

50% 50%

BG Group BP

25% 75%

BG Group 28.89% Other Train 4 partners off-take equity entitlement 71.11%

DOWNSTREAM

Shareholders Atlantic LNG Train 1 (%)

26 34 20 10 10

Shareholders Atlantic LNG Trains 2 and 3 (%)

BG Group BP Repsol

32.5 42.5 25.0

Shareholders Atlantic LNG Train 4 (%)

BG Group BP Repsol NGC

28.89 37.78 22.22 11.11

BG Group Data Book 2007

NORTH AMERICA AND THE CARIBBEAN

Atlantic Trains 2, 3 and 4 represent fully integrated projects for BG Group, involving the production and liquefaction of gas in Trinidad and Tobago, the shipping of LNG to the USA and the subsequent regasification for onward sale into the US market.

LIQUEFACTION OUTPUT

BG Group BP Repsol Suez NGC

BG Group BP

LNG 28.9%

28.9%

UPSTREAM

60% 40%

LNG

25%

c800 mmscfd

Suez Gas Natural

LNG 32.5%

50%

Gas

BG Group and upstream partners

LNG PURCHASE

North America and the Caribbean and Global LNG 36

United States of America New information CANADA

• A 20 year Sale and Purchase Agreement signed for 2.25 mtpa from Nigeria LNG Train 7

Lake Road

• First cargoes lifted under Equatorial Guinea LNG contract

BOSTON

Masspower

Dighton

• Cypress pipeline in service giving direct access from Elba Island to the Florida market

Providence Proposed regas facility WASHINGTON D.C.

• Gas-fired power generation plants acquired

USA

Key dates Elba Island

2002 22 year lease for Lake Charles capacity 2003 Secured access to Elba Island terminal

Lake Charles JACKSONVILLE

2006 Two expansions of Lake Charles increase capacity to 13.4 mtpa, resulting in 5 year extension to the lease

HOUSTON

GULF OF MEXICO

Dighton generation facility acquired 0

1 000km

LNG: Long-term firm supply(a) Firm supply

Commercial start-up

Years

Shipping

Atlantic LNG Train 2/3

2.1

2003

20

FOB

Nigeria LNG Train 4/5

2.3

2006

20

CIF

Egyptian LNG Train 2

3.5

2006

20

FOB

Atlantic LNG Train 4

1.5

2006

20

FOB

Equatorial Guinea LNG

3.3

2007

17

FOB

Nigeria LNG Train 7(b)

2.3

2012

20

CIF

(a) Assumes volumes delivered into US East Coast (b) First delivery expected

2007 Lake Road and Masspower generation facilities acquired The US gas market is becoming increasingly dependent on LNG imports to fill the growing gap between demand and local (US and Canadian) supply. BG Group is the leading LNG importer in the USA with supply from both equity and third party projects. In 2006, BG Group was responsible for approximately 50% of US LNG imports. BG Group, through its subsidiary companies has established this leading position through a combination of its capacity at the Lake Charles and Elba Island LNG receiving terminals, a portfolio of LNG supply contracts, its gas marketing capability and its access to shipping. BG Group is in a strong position to build on both its supply and marketing positions in the USA through expansion of existing facilities and the pursuit of new projects. With the acquisition of the Dighton power plant in September 2006, BG Group initiated expansion into the US merchant power business as a complement to its existing natural gas business. With the acquisition of two additional facilities, Lake Road and Masspower in early 2007, the generation portfolio includes average capacity of 1 214 MW . LAKE CHARLES In 2001, BG LNG Services (BGLS), a whollyowned BG Group subsidiary, signed a 22 year LNG Terminalling Service Agreement to utilise the available capacity of the LNG import facility at Lake Charles, Louisiana, USA.

BG Group Data Book 2007

37

The Agreement became effective in January 2002 and was extended in January 2004 to cover 100% of the terminal capacity for the term of the Agreement. The terminal has access to 15 major intrastate and interstate natural gas pipelines through the Trunkline Gas Pipeline system. In 2002, the terminal had the capability to deliver an average daily send-out of 630 mmscfd gas on a sustainable basis and 1 bcfd on a peaking basis. The Lake Charles facility has undergone two expansions to increase sustainable baseload capacity to 1.8 bcfd (with peak capacity of 2.1 bcfd), completed in July 2006, and added a second unloading berth. All of the capacity of the expansions is committed to BGLS. BGLS entered into a long-term agreement with Trunkline Gas Company for pipeline capacity sufficient to meet its increasing throughput capability at Lake Charles from 1 April 2004 onwards. The agreement provides for the addition of new pipeline facilities and upgrades of existing facilities. The installation of the upgrades in July 2005 allows BGLS increased access to the US pipeline grid, providing enhanced access to diverse and deep markets.

ELBA ISLAND Beginning in 2004, BGLS established itself as the new marketer of regasified LNG at Elba Island in Georgia after taking over contracted capacity and long-term LNG supply from El Paso in late 2003. Additionally, BGLS entered into a longterm transportation arrangement with Southern Natural Gas to construct the Cypress pipeline expansion of the Southern Natural Gas Pipeline running from Elba Island to Jacksonville, Florida. This pipeline extension is now in service, debottlenecking BGLS’ access to the Southern Natural Gas Pipeline and connecting Elba Island to growing local markets in Georgia and Florida. In 2005, Southern Natural Gas, the terminal owner, announced it will expand

PROVIDENCE In a joint initiative with KeySpan Corporation, the largest natural gas distributor in northeast USA, BGLS had proposed an upgrade of KeySpan’s existing LNG storage peak-shaving facility in Providence, Rhode Island, to allow marine deliveries. In July 2005, FERC issued an order denying authorisation of the project’s certificate under Section 3 of the Natural Gas Act, citing concerns regarding the existing LNG tank (built in 1974) and its non-compliance with current federal safety standards for new construction. BG Group and KeySpan continue to review the options relating to this business opportunity. LNG SUPPLY BG Group is pursuing a number of options to create a diversified supply portfolio for its LNG regasification capacity. These options include buying LNG from third parties as well as from BG Group equity LNG liquefaction projects. The portfolio has a variety of contract periods and comprises a mixture of free on board (FOB), where the buyer arranges carriage, and carriage, insurance and freight (CIF) deals. Details on BG Group’s long-term firm supply can be found in the table on page 36. BG Gas Marketing (BGGM) also has a contract with Egyptian General Petroleum Corporation (EGPC), Egyptian Natural Gas Holding Company (EGAS) and PETRONAS for the export of natural gas via the SEGAS LNG plant located in Damietta, Egypt. The agreement allows BG Group and its Egyptian LNG partners to toll approximately 225 mmscfd gas through the plant for five years. BG Group lifted its first cargo in March 2005.

NORTH AMERICA AND THE CARIBBEAN

In March 2006, BGLS signed an agreement with Trunkline LNG, the owner of the Lake Charles terminal, for upgrades to the facility including an ambient air vaporisation system and a natural gas liquids extraction plant to remove higher Btu products such as ethane and propane from the LNG. The new system will reduce fuel gas consumption, thus enhancing margins, reduce emissions, and provide an additional revenue stream from NGL sales expected to start in third quarter 2008. As part of the agreement, Trunkline has also extended BGLS’s rights as the sole capacity holder by five years until 2028.

the total terminal capacity to just over 2 bcfd, of which BG Group currently has 0.57 bcfd. BGLS agreed with Southern Natural Gas that it will, by the start of 2014, increase its share of capacity to 1.17 bcfd.

BG Group is participating in a joint project to develop a liquefaction plant in Olokola (OKLNG) on the south-western coast of Nigeria. BG Group has a 13.5% share in the project and all shareholders will have the right to lift their equity share of LNG. In January 2006, BGGM announced that it had entered into a Memorandum of Understanding with the Brass LNG consortium in Nigeria. The proposed Sale and Purchase Agreement is expected to provide 1.67 mtpa for the Group’s portfolio on a 20 year term, with initial deliveries expected to commence during 2012. It is planned that cargoes will be delivered on an ex-ship basis to Lake Charles and Elba Island. BG Group Data Book 2007

North America and the Caribbean and Global LNG 38

United States of America continued MARKETING BG LNG Trading (BGLT) in conjunction with the Group’s LNG shipping organisation is engaged in marketing LNG to buyers throughout the world. During 2006, BGLT diverted 71 cargoes from their intended destinations in the US to higher value markets. The combination of flexible supply, shipping capacity and commercial capability gives BG Group a strategic advantage. BG Energy Merchants (BGEM) markets regasified LNG from Lake Charles and Elba Island, along with indigenous gas supplies, to multiple intermediary and end use customers via delivery through the US natural gas pipeline infrastructure. Sales are made under various short-, mediumand long-term arrangements. BGEM’s customers include leading gas and electric utilities, as well as industrial and wholesale gas merchants. In 2006, BGEM’s marketing activities in the USA met 1.3% of the daily US gas demand (data source: EIA). SHIPPING BG Group has a long history in LNG shipping, having been involved in the development of both the prototype and the first working LNG carriers in the industry. BG Group’s present activities in this area are primarily directed towards meeting the needs of BG Group projects. In June 2004, BG Group took delivery of its first new ship, the Methane Kari Elin (138 000 cubic metres). Since then BG Group has taken delivery of six more 145 000 cubic metre ships: the Methane Rita Andrea; the Methane Lydon Volney; the Methane Jane Elizabeth; the Methane Heather Sally; the Methane Shirley

Elizabeth and the Methane Alison Victoria. The Methane Nile Eagle is scheduled for delivery in December 2007 and two new owned additional ships are ordered for delivery in 2009 and 2010, respectively. These two new ships will be larger (170 000 cubic metres) and powered by dual-fuel diesel-electric engines which are more efficient and produce less emissions. BG Group contracts additional shipping as required on a short-, medium- and long-term basis in order to capture business opportunities and maintain a balanced shipping position (see page 50 for further details). STORAGE In addition to the significant inherent storage facilities at Lake Charles and Elba Island, BG Group will from time to time contract for natural gas storage capacity on a seasonal and/or medium- to longterm basis to facilitate its operational and commercial requirements. POWER BG Group entered the north-east US power market in 2006, chosen as a market that is both mature and transparent with no dominant incumbents. The first power station purchased was Dighton, followed by Lake Road and then Masspower (see panel below for more detail). The assets selected have been chosen to generate additional synergies from BG Group’s existing integrated gas business. This will be via gas supply, plant operations and power marketing.

US Power portfolio: Integrated gas marketing The Dighton, Lake Road and Masspower acquisitions, all 100% owned by BG Group, represent an important step in the implementation of the Group’s integrated US gas marketing strategy.

Lake Road

Masspower

BOSTON

Dighton

USA

Power generation has the potential to offer BG Group attractive returns and is readily integrated into the Group’s growing US gas business to generate additional returns.

Dighton Capacity: 165 MW*

All three plants’ output is sold into the competitive New England power market.

Lake Road Capacity: 785 MW*

Dighton is designed to run on natural gas, which can be supplied by BG Group through the Algonquin pipeline system.

Masspower Capacity: 264 MW*

BG Group Data Book 2007

*ISO-NE weighted average annual installed capacity ratings

Both Lake Road and Masspower are dual fuel capable plants designed to run on natural gas or #2 distillate oil. Fuel to Lake Road is supplied through the Algonquin pipeline system while Masspower is supplied through the Tennessee Gas pipeline system. With both plants the primary fuel is natural gas with distillate as the back-up fuel. The ability to switch fuels gives the plants a commercial advantage over gas-only plants in the region.

Statistical supplement

39

CONTENTS 40 Introduction and legal notices Social and environment data 41 Environment 41 Our People 41 Society 41 Conduct Group financial data 42 Summarised BG Group annual results 43 Summarised BG Group quarterly results 44 Segmental analysis Exploration and Production 45 Estimated net proved reserves of natural gas 46 Estimated net proved reserves of oil 46 Estimated net proved and probable reserves 47 Operating statistics 47 Drilling activity 48 Field interests 49 Licence and block interests LNG 50 Facilities capacity 50 Long-term firm supply 50 Cargoes 51 Ships Transmission and Distribution 51 Operating statistics Power 51 Capacity Corporate information 52 Principal acquisitions, commitments and divestments 52 Credit Ratings

STATISTICAL SUPPLEMENT

53 Issued share capital and dividend history 53 Investor calendar Definitions and conversions 54 Definitions

BG Group Data Book 2007

40

Introduction and legal notices INTRODUCTION

Financial and operating statistics This financial and operating information includes extracts from the BG Group Annual Report and Accounts 2006 and quarterly results statements. Reference to these reports will assist in the understanding of the figures in this document. The financial information in this document is unaudited and is not intended to be the statutory accounts of BG Group plc.

International Financial Reporting Standards BG Group plc has adopted International Financial Reporting Standards (IFRS) as its primary accounting basis for the year ending 31 December 2006. Restatement of the 2003 and 2004 financial results and the principal accounting policies under IFRS are available in the BG Group Annual Report and Accounts 2005.

Business Performance ‘Business Performance’ excludes disposals, certain re-measurements and impairments and exclusion of these items provides readers with a clear and consistent presentation of the underlying operating performance of the Group’s ongoing business. For further explanation of Business Performance and the presentation of results from joint ventures and associates, please refer to the presentation of non-GAAP measures on page 152 of the BG Group Annual Report and Accounts 2006.

Translation into US Dollars Some of BG Group’s financial figures in Sterling have been translated into US Dollars. The average rate for each year has been used when translating the income statement and cash flow statement. These translations should not be construed as representations that the Sterling amounts actually represent such US Dollar amounts or could be converted into US Dollars at the rate indicated or any other rate.

LEGAL NOTICES Steps have been taken to verify the information contained in this Data Book and, unless otherwise indicated, is believed to be accurate as at 31 July 2007. However, neither BG Group plc nor any of its subsidiary undertakings, joint ventures or associated undertakings or their respective directors, partners, employees or agents make any representation or warranty, express or implied, or accepts any responsibility, with respect to the accuracy or completeness of the information in this document. Nothing in this document constitutes or shall be taken to constitute an offer, invitation or inducement to any person to invest in BG Group and no reliance should be placed on the information contained in it in connection with any investment decision.

Forward-looking information This Data Book includes ‘forward-looking information’ within the meaning of Section 27A of the US Securities Act of 1933, as amended, and Section 21E of the US Securities Exchange Act of 1934, as amended. Certain statements included in this Data Book, including without limitation, those concerning: strategies, outlook and growth opportunities; positioning to deliver future plans and to realise potential for growth; delivery of the performance required to meet the 2007 targets; expectations regarding gas and oil prices; development of new markets; the development and commencement of commercial operations of new projects; liquidity and capital resources; gas demand growth; plans for capital investment; the economic outlook for the gas and oil industries; regulation; qualitative and quantitative disclosures about market risk; and statements preceded by ‘expected’, ‘scheduled’, ‘targeted’, ‘planned’, ‘proposed’, ‘intended’ or similar statements contain certain forward-looking information concerning the Group’s operations, economic performance and financial condition. Although BG Group believes that the assumptions and expectations reflected in such forward-looking statements are reasonable, no assurance can be given that these will prove to have been correct. Actual results could, therefore, differ materially from those set out in the forward-looking statements as a result of, among other factors: changes in economic, market and operational conditions, including supply and demand for gas and oil and gas and oil prices;

success in implementing business and operating initiatives; changes in the regulatory environment and other government actions, including UK and international corporation tax rates; a major recession or significant upheaval in the major markets in which the Group operates; the failure to ensure the safe operation of the Group’s assets worldwide; implementation risk, being the challenges associated with delivering capital intensive projects on time and on budget, including the need to retain and motivate staff; business risk management; commodity risk, being the risk of a significant fluctuation in gas and/or oil prices from those assumed; fluctuations in exchange rates, in particular the US$/UK£ exchange rate being significantly different from that assumed; risks inherent in project delivery and in the gas and oil exploration and production sector in general; the failure of co-venturers to meet contractual obligations; political instability, natural disasters and adverse weather conditions; and war, sabotage and acts of terrorism. For a more detailed analysis of the factors that may affect BG Group, please refer to the Risk Factors on pages 41 to 44 of the BG Group Annual Report and Accounts 2006. BG Group undertakes no obligation to update any forward-looking statements.

Cautionary note to US investors The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. We use certain terms in this document such as ‘probable reserves’, that the SEC’s guidelines strictly prohibit us from including in filings with the SEC. US investors are urged to consider closely the disclosure in our Form 20-F, File No. 1-09337, available from us at BG Group, 100 Thames Valley Park Drive, Reading RG6 1PT. You may read and copy this information at the SEC’s public reference room, located at 100F Street N.E., Washington D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the public reference room. This filing is also available on the website www.sec.gov maintained by the SEC.

Details of disposals, certain re-measurements and impairments can be found on the BG Group website, www.bg-group.com The information contained in the Data Book can also be found on the BG Group website, www.bg-group.com

BG Group Data Book 2007

Social and environment data

41

ENVIRONMENT

The data in the tables below represents 100% of the direct emissions, discharges and wastes from the activities shown below and 50% from our joint operated venture in Kazakhstan: • E&P operations where BG Group is designated as the ‘operator’; and • LNG, T&D and Power operations in which BG Group holds a total interest of over 50%. This includes MetroGAS S.A., which is controlled by BG Group (although BG Group’s direct shareholding is less than 50%).

Emissions (tonnes) Carbon dioxide

Venting

Fugitive

Flaring

Fuel use

Electricity generation

Distribution losses

Total 2006

Total 2005

Total 2004

t/mmboe 2006

t/mmboe 2005

t/mmboe 2004

14 002

526 175

2

427 465

1 989 336

2 105 507

1 262

5 049 747

5 404 117

4 162 328

15 081

15 854

Carbon monoxide

0

0

1 554

3 741

3 346

0

8 641

39 331

10 356

26

115

35

Nitrogen oxides

0

0

419

10 615

2 440

0

13 474

11 685

11 767

40

34

40

Sulphur dioxide

0

0

4 642

3 798

1 375

0

9 815

17 913

25 513

29

53

86

5 555

849

1 371

352

227

36 469

44 823

48 427

47 139

134

142

159

6 640

158

585

209

76

2 950

10 618

10 467

9 636

32

31

32

642 840

17 819

461 880

2 013 665

2 128 594

767 107

6 031 905

6 468 275

5 242 001

18 014

18 976

17 631

Oil in process water

Oil on cuttings

Oil spills

Process water

Drill cuttings

Total 2006

Total 2005

Total 2004

207

124

0.1

4 356 505

25 698

4 382 534

Metal

General

Hazardous

Drill cuttings

Total 2006

Total 2005

1 511

24 112

28 523

13 803

67 949(2)

23 534(3)

Gas

Electricity

Oil

Total 2006

Total 2005

Total 2004

8 167 437

43 020

1 239 859

9 450 316

8 682 281

5 634 718

Methane Volatile organic compounds Greenhouse gases (carbon dioxide equivalent)

Discharges to aqueous environments (tonnes)

Waste for disposal (tonnes)

Energy use (MWh)

(1) (2) (3)

3 867 907(1)

3 068 125 Total 2004

43 159

Amended from 2005 CR Report to include KPO data not available at the time of the 2005 Report Of the 67 949 tonnes, 34 569 tonnes was recycled Amended from 2005 CR Report to include drilling waste data not available at the time of the 2005 Report

OUR PEOPLE

People

People data refers to direct employees of BG Group. Employees worldwide(1) Employees based outside UK(1) Employees working away from home country Women in management (1) (2)

2006

2005

4 665

5 363(2)

2004

5 175

3 030

4 000(2)

3 912

529

440

452

9%

11%

12%

Average numbers throughout 2005 and 2006 Included in this figure are an average of 1 009 employees of MetroGAS S.A. This company was deconsolidated at the end of 2005

Health and Safety

The statistics represent 100% of the data from the aforementioned operations plus the operations at Dragon LNG, UK and Egyptian LNG and Nile Valley Gas Company, Egypt, in which BG Group holds an interest of less than 50% but BG Group employees hold high-level management positions. Lost time injury frequency (LTIF) Total recordable case frequency (TRCF) Sickness absence Reported occupational related illness frequency (ORIF)

2006

2005

0.36

0.51

0.55

1.66

2.39

2.49

0.4

0.4

0.5

0.1

0.1

0.2

2006

2005

2004

7

6

–

24(1)

7

2

CONDUCT Investigations of fraud allegations Whistleblowing cases (1)

2004

A review and promotion of the Group’s Whistleblowing Policy during 2006 lead to increased awareness of this policy and subsequent increase in the number of reported cases

SOCIETY

Social investment

Charitable donations Community investment Commercial initiatives Management costs

2006

2005

2004

426 663

1 064 441

855 432

1 364 205

1 508 691

843 804

1 978 555

808 014

1 530 500

470 966

260 357

264 978

4 240 389

3 641 503

3 494 714

Contractual

1 352 053

3 503 761

5 661 765

Total voluntary and contractual contributions

5 592 442

7 145 264

9 156 479

Sub-total voluntary contributions

BG Group Data Book 2007

STATISTICAL SUPPLEMENT

These represent 100% of contributions made by wholly owned BG Group businesses and proportional contributions (according to BG Group’s stake) made by operations and joint ventures where BG Group is a shareholder.

42

Summarised BG Group annual results BUSINESS PERFORMANCE 2006

Dated Brent average ($/bbl) FX rate ($/£) Henry Hub ($/mmbtu)

2005(1)

2004(1)

65.14

54.52

38.26

1.83

1.83

1.82

6.74

8.86

5.85

BG Group E&P production (mmboe)

219.2

183.8

166.8

Group revenue and other operating income (£ million)

7 270

5 664

4 063

2 457

1 942

1 189

352

181

99

Transmission and Distribution

231

211

148

Power

106

113

116

(43)

(58)

(32)

3 103

2 389

1 520

(43)

(65)

(79)

3 060

2 324

1 441

(1 375)

(939)

(587)

1 685

1 385

854

(45)

(31)

(28)

Earnings

1 640

1 354

826

Earnings per ordinary share

47.4p

38.2p

23.4p

Net cash flow from operating activities

2 381

1 626

1 212

(103)

(30)

(1 186)

Total operating profit Exploration and Production LNG

(2)

Other activities

Total operating profit on ordinary activities (3)

Net finance costs

Profit on ordinary activities before taxation Tax on profit on ordinary activities

(4)

Profit on ordinary activities after taxation Minority shareholders’ interest

Net borrowings Capital investment

1 847

1 595

1 894

Capital investment excluding acquisitions

1 800

1 566

1 373

26.2

22.6

17.3

1.6

0.4

20.6

ROACE after tax (%) Gearing (%) (1) (2) (3) (4)

Restated under IFRS and for IFRIC 4. For further detail, please see the www.bg-group.com website Other activities include new business development expenditure and certain corporate costs Includes share of joint ventures and associates net finance costs Includes share of joint ventures and associates tax

BG Group Data Book 2007

Summarised BG Group quarterly results(1) (2)

43

BUSINESS PERFORMANCE Dated Brent assumption $/bbl

Q2 2007

Q1 2007

Q4 2006

Q3 2006

Q2 2006

Q1 2006

Q4 2005

Q3 2005

Q2 2005

Q1 2005

Q4 2004

Q3 2004

Q2 2004

Q1 2004

31.81

68.76

57.76

59.60

69.60

69.59

61.79

56.87

61.63

51.63

47.62

44.01

41.29

35.35

FX rate $/£

1.98

1.96

1.90

1.86

1.80

1.75

1.76

1.79

1.87

1.90

1.85

1.81

1.81

1.82

Henry Hub $/mmbtu

7.55

7.16

6.60

6.08

6.54

7.75

12.22

9.82

7.03

6.37

6.26

5.44

6.08

5.62

BG Group E&P production (mmboe)

53.7

58.2

57.2

50.6

55.6

55.8

54.3

41.2

44.6

43.7

45.0

39.7

41.2

40.9

– oil volume (mmboe)

7.4

6.5

5.9

4.3

5.3

5.6

5.5

4.6

4.5

4.7

5.8

4.8

5.3

5.5

– liquids volume (mmboe)

9.7

8.8

8.7

6.9

7.6

7.4

7.8

5.8

8.4

7.7

7.8

6.4

5.7

5.7

36.6

42.9

42.6

39.4

42.7

42.8

41.0

30.8

31.7

31.3

31.4

28.5

30.2

29.7

BG Group avg UK gas price pence per produced therm

23.88

37.03

34.41

25.50

26.20

38.84

38.89

20.10

22.98

24.12

22.59

18.33

17.89

19.68

BG Group avg Int’l gas price pence per produced therm

15.11

16.31

16.69

16.83

17.05

18.4

21.43

17.92

14.16

13.85

14.66

14.17

13.83

12.99

Overall BG Group avg gas price pence per produced therm

17.00

21.50

21.28

18.52

19.09

23.69

26.11

18.42

16.81

17.48

17.55

15.71

15.40

15.97

BG Group avg oil price $/bbl

69.07

58.13

60.13

71.43

69.76

62.53

58.55

63.02

52.36

48.24

45.58

42.80

36.17

32.56

BG Group avg liquids price $/bbl

56.72

45.57

46.40

57.56

56.79

50.17

47.17

48.23

39.54

33.01

31.28

30.56

22.59

16.27

264

– gas volume (mmboe)(3)

Total operating profit including share of pre-tax operating results from joint ventures and associates £ million Exploration and Production

565

626

575

509

647

726

729

419

407

387

360

291

274

LNG

88

121

115

65

34

138

81

54

17

29

23

39

21

16

Transmission and Distribution

70

50

53

56

57

65

45

64

56

46

31

51

36

30

Power

31

38

28

16

23

39

35

21

21

36

34

21

24

37

Other activities(4)

(7)

(12)

(11)

(13)

(9)

(10)

(30)

(7)

(8)

(13)

(11)

(5)

(6)

(10)

Total operating profit Net finance costs(5)

747

823

760

633

752

958

860

551

493

485

437

397

349

337

(6)

(9)

(17)

(13)

(14)

1

(17)

(14)

(13)

(21)

(23)

(19)

(18)

(19)

Profit before tax Tax on profit on ordinary activities(6)

741

814

743

620

738

959

843

537

480

464

414

378

331

318

(317)

(356)

(324)

(266)

(401)

(384)

(346)

(215)

(191)

(187)

(176)

(151)

(132)

(128)

Profit for the period Minority interest

424

458

419

354

337

575

497

322

289

277

238

227

199

190

(15)

(10)

(9)

(12)

(12)

(12)

6

(15)

(14)

(8)

(2)

(14)

(7)

(5)

Earnings (BG Group shareholders) (7)

409

448

410

342

325

563

503

307

275

269

236

213

192

185

Earnings per ordinary share

12.0p

13.1p

12.0p

10.0p

9.3p

16.0p

14.2p

Net cash flow from operating activities Net (borrowings)/funds Capital investment

639

902

577

461

641

702

369

469

213

(27)

(103)

(358)

14

183

(30)

(380)

496

869

549

511

401

386

408

457

415

315

509

356

402

627

Capital investment excluding acquisitions

422

438

502

511

401

386

408

457

386

315

389

325

292

367

8.6p

7.8p

7.6p

6.7p

378

410

316

(245) (1 095)

6.1p

5.4p

5.2p

358

236

302

(1 186) (1 206)

(1 154)

(1 179)

ADDITIONAL INFORMATION: EXPLORATION AND PRODUCTION Lifting costs ($/boe) – lifting costs (£/boe) Opex ($/boe) – opex (£/boe) Development expenditure (£ million) Gross exploration expenditure (£ million) – capitalised – other expenditure (1) (2) (3) (4) (5) (6) (7)

$3.44

$2.97

$2.88

$2.69

$2.18

$2.08

$1.92

$2.54

$2.10

$2.18

$1.83

$2.20

$1.93

$1.60

£1.74

£1.51

£1.51

£1.45

£1.21

£1.19

£1.09

£1.42

£1.13

£1.15

£0.99

£1.22

£1.07

£0.88

$5.41

$4.92

$4.82

$4.39

$3.72

$3.82

$3.85

$4.57

$3.82

$3.96

$3.60

$4.01

$3.78

$3.28

£2.74

£2.51

£2.53

£2.36

£2.07

£2.18

£2.19

£2.56

£2.04

£2.08

£1.95

£2.21

£2.09

£1.80

301

291

201

229

160

131

188

166

174

155

205

151

125

139

102

105

180

103

103

169

131

65

38

102

122

93

63

58

46

59

129

65

66

136

89

34

15

87

92

75

50

45

56

46

51

38

37

33

42

31

23

15

30

18

13

13

All information is prepared under IFRS BG Group has applied IFRIC 4 from 1 January 2006. Comparative information for 2005 and 2004 has been restated for IFRIC 4. For further detail, please see the www.bg-group.com website Volumes from 2006 onwards include fuel gas. Volumes for 2005 and 2004 do not include fuel gas Other activities include new business development expenditure and certain corporate costs Includes share of joint ventures and associates net finance costs Includes share of joint ventures and associates tax Q2 2006 includes prior period taxation of £76 million due to increase in North Sea taxation

STATISTICAL SUPPLEMENT BG Group Data Book 2007

44

Segmental analysis(1) BUSINESS PERFORMANCE Q2 2007

Q1 2007

Year 2006

Q4 2006

Q3 2006

Q2 2006

Q1 2006

Year 2005

Q4 2005

Q3 2005

Exploration and Production

942

1 027

3 928

LNG

910

697

2 442

1 001

870

984

1 073

3 074

1 093

688

658

635

2 148

675

566

548

653

1 631

771

404

236

220

1 098

Transmission and Distribution

234

220

877

226

224

224

203

808

219

224

196

169

644

Power

142

96

248

64

42

50

92

227

59

47

46

75

Other activities(2)

1

2

8

1

2

2

3

15

5

4

4

Intra-group sales

(67)

(62)

(233)

(70)

(57)

(54)

(52)

(91)

(49)

(28)

2 162

1 980

7 270

1 897

1 647

1 754

1 972

5 664

2 098

565

626

2 457

575

509

647

726

1 942

57

96

248

90

40

10

108

70

Transmission and Distribution Power

59

40

190

44

46

46

54

169

10

18

18

7

(1)

2

10

24

8

1

(1)

16

28

12

1

1

14

Other activities

(7)

(12)

(43)

(11)

(13)

(9)

(10)

(58)

(30)

(7)

(8)

(13)

(32)

(11)

(5)

(6)

(10)

£ million

Q2 2005

Q1 2005

Year 2004

Q4 2004

Q3 2004

Q2 2004

Q1 2004

650

534

488

476

296

336

276

190

165

178

162

139

187

55

40

38

54

2

8

2

3

2

1

(7)

(7)

(22)

(7)

(7)

(4)

(4)

1 339

1 133

1 094

4 063

1 161

1 084

962

856

729

419

407

387

1 189

360

291

274

264

45

24

(7)

8

34

7

20

5

2

34

54

46

35

108

22

41

25

20

Revenue and other operating income

OPERATING PROFIT Group operating profit before share of pre-tax results of joint ventures and associates Exploration and Production LNG

Sub-total Group operating profit

684

768

2 870

705

581

696

888

2 147

786

491

437

433

1 327

390

348

299

290

Share of operating profit of joint ventures and associates Exploration and Production

–

–

–

–

–

–

–

–

–

–

–

–

–

–

–

–

–

LNG Transmission and Distribution

31

25

104

25

25

24

30

111

36

30

24

21

65

16

19

16

14

11

10

41

9

10

11

11

42

11

10

10

11

40

9

10

11

10

Power Other activities

21

20

88

21

17

21

29

89

27

20

22

20

88

22

20

23

23

–

–

–

–

–

–

–

–

–

–

–

–

–

–

–

–

–

Sub-total share of operating profit in joint ventures and associates Total operating profit (1) (2)

63

55

233

55

52

56

70

242

74

60

56

52

193

47

49

50

47

747

823

3 103

760

633

752

958

2389

860

551

493

485

1 520

437

397

349

337

BG Group has applied IFRIC 4 from 1 January 2006. Comparative information for 2005 and 2004 has been restated for IFRIC 4. For further detail, please see the www.bg-group.com website Other activities include new business development expenditure and certain corporate costs

BG Group Data Book 2007

Exploration and Production: Estimated net proved reserves of natural gas

45

The allocation of the countries within these areas is: Atlantic Basin – Canada, Egypt, Nigeria, Trinidad and Tobago and the USA Asia and the Middle East – China, India, Kazakhstan, Oman, Thailand, Israel and areas of Palestinian Authority Rest of the world – Algeria, Bolivia, Brazil, Italy, Libya, Madagascar, Mauritania, Norway, Spain and Tunisia

As at 31 December 2003

UK bcf

Atlantic Basin bcf

Asia and Middle East bcf

Rest of world bcf

Total bcf

1 116

4 167

2 286

1 189

8 758

184

162

249

75

670

8

–

–

–

8

(269)

(216)

(149)

(85)

(719)

–

359

–

–

359

Movement during the year: (1)

Revisions of previous estimates

Extensions, discoveries and reclassifications Production Purchase of reserves-in-place Sale of reserves-in-place As at 31 December 2004

–

–

–

–

–

(77)

305

100

(10)

318

1 039

4 472

2 386

1 179

9 076

297

392

402

209

1 300

7

16

–

74

97

(219)

(332)

(158)

(96)

(805)

Movement during the year: (1)

Revisions of previous estimates

Extensions, discoveries and reclassifications Production Purchase of reserves-in-place

–

–

–

–

–

Sale of reserves-in-place

–

(1)

–

–

(1)

85

75

244

187

591

1 124

4 547

2 630

1 366

9 667

Revisions of previous estimates

80

583

145

20

828

Extensions, discoveries and reclassifications

87

–

–

–

87

(223)

(515)

(170)

(92)

(1 000)

Purchase of reserves-in-place

–

–

–

–

–

Sale of reserves-in-place

–

–

–

–

–

As at 31 December 2005

(2)

Movement during the year: (1)

Production

(56)

68

(25)

(72)

(85)

1 068

4 615

2 605

1 294

9 582

As at 31 December 2003

949

1 484

1 732

789

4 954

As at 31 December 2004

867

1 393

2 038

665

4 963

As at 31 December 2005

937

2 267

2 139

929

6 272

As at 31 December 2006

846

2 232

2 006

844

5 928

As at 31 December 2006

(2)

Proved developed reserves of natural gas:

(1) (2)

Includes effect of oil and gas price changes on PSCs Estimates of proved natural gas reserves at 31 December 2006 include fuel gas of 640 bcf (31 December 2005 534 bcf)

STATISTICAL SUPPLEMENT BG Group Data Book 2007

46

Exploration and Production: Estimated net proved reserves of oil ‘Oil’ includes crude oil, condensate and natural gas liquids.

As at 31 December 2003

UK mmbbl

Atlantic Basin mmbbl

Asia and Middle East mmbbl

Rest of world mmbbl

Total mmbbl

162.7

9.8

440.6

31.5

644.6

21.7

–

(3.1)

6.1

24.7

1.3

–

–

9.8

11.1

Movement during the year: (1)

Revisions of previous estimates

Extensions, discoveries and reclassifications Production

(21.2)

(0.3)

(23.3)

(2.2)

(47.0)

Purchase of reserves-in-place

–

1.4

–

–

1.4

Sale of reserves-in-place

–

–

–

–

1.8

1.1

(26.4)

13.7

(9.8)

164.5

10.9

414.2

45.2

634.8

12.3

7.7

(46.9)

4.5

(22.4)

1.5

–

–

7.4

8.9

(18.3)

(0.5)

(27.4)

(2.8)

(49.0)

–

–

–

–

–

As at 31 December 2004

–

Movement during the year: (1)

Revisions of previous estimates

Extensions, discoveries and reclassifications Production Purchase of reserves-in-place Sale of reserves-in-place

–

–

–

–

(4.5)

7.2

(74.3)

9.1

(62.5)

160.0

18.1

339.9

54.3

572.3

Revisions of previous estimates

10.0

(1.5)

18.4

(5.4)

21.5

Extensions, discoveries and reclassifications

10.2

–

–

–

10.2 (51.7)

As at 31 December 2005

–

Movement during the year: (1)

Production

(18.4)

(1.8)

(28.1)

(3.4)

Purchase of reserves-in-place

–

–

–

–

–

Sale of reserves-in-place

–

–

–

–

–

1.8

(3.3)

(9.7)

(8.8)

(20.0)

161.8

14.8

330.2

45.5

552.3

As at 31 December 2003

86.3

0.9

404.8

18.5

510.5

As at 31 December 2004

87.1

1.6

382.3

20.4

491.4

As at 31 December 2005

80.9

9.4

313.8

26.3

430.4

As at 31 December 2006

116.2

7.6

282.2

26.1

432.1

As at 31 December 2006 Proved developed reserves of oil:

(1)

Includes effect of oil and gas price changes on PSCs

Exploration and Production: Estimated net proved and probable reserves(1) DEVELOPMENT STATUS Gas bcf

Oil(2) mmbbl

Total(3) mmboe

As at 31 December 2006 Fields in production

14 611

784

3 219

Fields under development

197

136

169

Fields awaiting development

713

25

144

15 521

945

3 532

Total (1) (2) (3)

Gas and oil reserves cannot be measured exactly since estimation of reserves involves subjective judgement. Therefore all estimates are subject to revision Oil includes crude oil, condensate and natural gas liquids Conversion rate of 6 bcf gas per mmboe

BG Group Data Book 2007

Exploration and Production: Operating statistics

47

Production volumes (mmboe) Q2 2007

Q1 2007

Year 2006

Q4 2006

Q3 2006

Q2 2006

Q1 2006

Year 2005

Q4 2005

Q3 2005

Q2 2005

Q1 2005

Year 2004

Q4 2004

Q3 2004

Q2 2004

Q1 2004

5.5

– oil volume mmboe

7.4

6.5

21.1

5.9

4.3

5.3

5.6

19.3

5.5

4.6

4.5

4.7

21.4

5.8

4.8

5.3

– liquids volume mmboe

9.7

8.8

30.6

8.7

6.9

7.6

7.4

29.7

7.8

5.8

8.4

7.7

25.6

7.8

6.4

5.7

5.7

36.6

42.9

167.5

42.6

39.4

42.7

42.8

134.8

41.0

30.8

31.7

31.3

119.8

31.4

28.5

30.2

29.7

BG Group avg UK gas price pence per produced therm

23.88

37.03

31.89

34.41

25.50

26.20

38.84

27.30

38.89

20.10

22.98

24.12

19.64

22.59

18.33

17.89

19.68

BG Group avg Int’l gas price pence per produced therm

– gas volume mmboe(1) Prices

15.11

16.31

17.23

16.69

16.83

17.05

18.40

17.27

21.43

17.92

14.16

13.85

13.95

14.66

14.17

13.83

12.99

Overall BG Group avg gas price pence per produced therm

17.00

21.50

20.68

21.28

18.52

19.09

23.69

20.15

26.11

18.42

16.81

17.48

16.18

17.55

15.71

15.40

15.97

BG Group avg oil price $ per barrel

69.07

58.13

65.54

60.13

71.43

69.76

62.53

55.96

58.55

63.02

52.36

48.24

39.24

45.58

42.80

36.17

32.56

BG Group avg liquids price $ per barrel

56.72

45.57

52.68

46.40

57.56

56.79

50.17

41.77

47.17

48.23

39.54

33.01

25.90

31.28

30.56

22.59

16.27

Henry Hub $/mmbtu Unit costs

7.55

7.16

6.74

6.60

6.08

6.54

7.75

8.86

12.22

9.82

7.03

6.37

5.85

6.26

5.44

6.08

5.62

Lifting costs ($/boe) Lifting costs (£/boe)

3.44

2.97

2.45

2.88

2.69

2.18

2.08

2.17

1.92

2.54

2.10

2.18

1.88

1.83

2.20

1.93

1.60

1.74

1.51

1.34

1.51

1.45

1.21

1.19

1.19

1.09

1.42

1.13

1.15

1.03

0.99

1.22

1.07

0.88

5.41

4.92

4.18

4.82

4.39

3.72

3.82

4.04

3.85

4.57

3.82

3.96

3.66

3.60

4.01

3.78

3.28

2.74

2.51

2.29

2.53

2.36

2.07

2.18

2.21

2.19

2.56

2.04

2.08

2.01

1.95

2.21

2.09

1.80

620

205

151

125

139

Opex ($/boe) Opex (£/boe) Finding and development costs 3 year rolling average ($/boe)(2)

11.50(3)

7.07(3)

4.84

108(3)

152(3)

248

Reserve replacement 3 year organic average reserve replacement ratio (%) Investment Development expenditure (£ million)

301

291

Gross exploration expenditure (£ million)

102 46 56

– capitalised – other expenditure (1) (2) (3)

721

201

229

160

131

683

188

166

174

155

105

555

180

103

103

169

336

59

396

129

65

66

136

225

131

65

38

102

336

122

93

63

58

89

34

15

87

262

92

75

50

46

159

51

38

37

33

111

45

42

31

23

15

74

30

18

13

13

From first quarter 2006 includes fuel gas The denominator uses the total net proved reserves changes over the three years excluding acquisitions, divestments and production These figures are calculated on a SEC basis, which includes all reserves revisions and fuel gas and is calculated at year end prices

Exploration and Production: Drilling activity WELL OPERATIONS Number of exploration and appraisal wells

2006

2005

2004

2003

2002

Total

42

29

28

17

25

Percentage successful (gross well basis)

56

48

64

71

72

WELLS DRILLED IN 2006: ANALYSIS BY COUNTRY

Exploration

Appraisal

Gross

Net

Gross

Net

12

10.41

–

–

4

2.00

–

–

India Brazil

–

–

2

0.60

4

2.50

–

–

Mauritania Trinidad and Tobago

2

0.25

–

–

1

0.65

–

–

UK Norway

12

4.40

–

–

1

0.20

–

–

Italy Thailand

1

0.50

–

–

3

0.67

–

–

40

21.57

2

0.60

Canada Egypt

Total

BG Group Data Book 2007

STATISTICAL SUPPLEMENT

The gross figure is a total number of wells in which BG Group participated The net figure is calculated by applying the licence working interest to each well and taking the sum of the fractional interests In the case of farm-ins and farm-outs, the working interest will be that which applies after completion of the well and consequent re-arrangement of interest

48

Exploration and Production: Field interests PRODUCING FIELDS

UKCS

(1)

Total production(2) (net) mmboe

2006

2005

2004

2006

2005

2004

2006

2005

2004

42.3

38.1

59.2

2 037

1 880

2 910

9.1

8.2

12.8

75.00 and 10.00

13.4

–

–

354

–

–

2.6

–

–

44.00

0.8

0.8

1.7

3 841

4 088

4 997

4.0

4.2

5.3

30.77 and 79.00

38.6

51.3

69.5

123

204

249

6.6

8.8

11.8

14.11

24.4

26.5

25.5

5 290

5 996

6 236

9.4

10.4

10.5

Easington Catchment Area(5) Elgin/Franklin Everest(4)

58.31

18.8

25.1

30.9

494

720

988

3.6

4.9

6.1

30.50 and 35.00

48.5

43.5

42.4

5 413

4 800

4 761

13.5

12.1

11.8

61.11

29.4

28.9

35.8

539

569

979

5.4

5.4

6.9

6.6

4.7

3.8

346

54

32

1.4

0.8

0.7

222.8

218.9

268.8

18 437

18 311

21 152

55.6

54.8

65.9

37.50 and 100.00

26.5

30.7

21.6

918

1 063

517

5.3

6.2

4.1

Various

19.8

19.0

15.8

162

176

208

3.5

3.3

2.9

50.00 and 80.00

365.4

209.9

84.7

1 530

259

89

62.4

35.3

14.2

30.00

37.5

35.5

31.7

4 050

3 504

2 854

10.3

9.4

8.1

32.50

82.3

75.7

70.0

22 585 22 399

18 991

36.3

35.0

30.7

0.2

–

–

949

–

–

1.0

–

–

22.22

50.3

47.0

47.6

1 440

1 440

1 501

9.8

9.3

9.5

45.88, 50.00 and 65.00

134.7

107.4

114.5

121

111

36

22.6

18.0

19.1

100.00

65.4

64.9

63.8

1 527

1 717

1 675

12.4

12.5

12.3

782.1

590.1

449.7

33 282 30 669

25 871

163.6

129.0

100.9

1 004.9

809.0

718.5

51 719 48 980 47 023

219.2

183.8

166.8

J-Block and Jade(6) Lomond Other UKCS sub-total Bolivia(7) Canada Egypt(3) India(3),(8) Kazakhstan(9) Mauritania(10) Thailand(11) Trinidad and Tobago(3) Tunisia(3)

Oil and liquids production (net) ‘000s barrels

46.77 and 57.00

Armada and SW Seymour(3), (4) Atlantic Cromarty Blake(3)

International

Gas production (net) bcf

BG Group working interest (%)

International sub-total Total

OTHER FIELDS AND DISCOVERIES WITH PROVED OR PROBABLE RESERVES: BG GROUP WORKING INTEREST (%) AS AT 31 DECEMBER 2006 UKCS

Glenelg Buzzard Maria(3) Jasmine NW Seymour(3)

14.70 21.73 36.00 30.50 57.00

Egypt

West Franklin Rashid-3, Rashid North, South Sequoia(3) Serpent, near field satellites, Mina, Silva, North Sequoia, Saurus(3) Bongkot South

50.00

Thailand Trinidad Tunisia

Starfish(3) Hasdrubal(3)

50.00

(1) (2) (3) (4) (5)

BG Group working interest at 31 December 2006 or when disposed of producing field Conversion rate of 6 bcf gas per mmboe Operated by BG Group at 31 December 2006 BG Group acquired a further 11.45% of Armada and 1.0134% of Everest fields on 30 March, 2007, taking the current stakes to 58.22% and 59.32% respectively Easington Catchment Area project comprises the Apollo, Mercury, Minerva, Neptune and Wollaston and Whittle fields BG Group-operated except for Wollaston and Whittle (6) J-Block includes Judy and Joanne (7) Includes Margarita Early Production Facility and the BG Group-operated and 100% owned La Vertiente fields (8) Jointly operated with ONGC and Reliance Industries (9) Joint operated in partnership with Eni (10) All interests in Mauritania sold in January 2007 (11) Includes Ton Sak

BG Group Data Book 2007

14.11 80.00 22.22 50.00

Exploration and Production: Licence and block interests

49

HELD AT 31 JULY 2007 Country

Interest Details

Algeria

Hassi Ba Hamou Perimeter

Bolivia(3)

XVIII La Vertiente Caipipendi Block XX Tarija West Block XX Tarija East Charagua Block Los Suris

Brazil

BM-S-9 BM-S-10 BM-S-11 BM-S-13 BM-S-47 BM-S-50 BM-S-52 BT-SF-2

Canada(3)

i) Alberta ii) British Columbia iii) Northwest Territories

Number of blocks

Waterton Foothills & Deep West Foothills Central Mackenzie Valley

BG Groupoperated

BG Group interest (%)

Unknown

1

36.75

Various Various Various Various Unknown Various

1 0 0 2 0 1

100 37.5 25 100 20 100

1 180 1 200 2 320 350 315 698 670 17 676

Various Gas Oil Oil Gas Oil Oil Gas

0 0 0 1 2 0 0 0

30 25 25 60 50 20 40 50

10 37 34 4

9 707 26 926 56 747 394 668

Gas Unknown Unknown Unknown

0 27 27 4

50 85 75 81

Gross area (1)

Type of fields (2)

5

18 381

1 1 1 2 1 1

38 246 25 15 79 5

1 1 1 1 2 1 1 6

China

Block 53/16 Block 64/11

1 1

8 671 7 546

Unknown Unknown

1 1

100 100

Egypt

Rosetta Concession(4) West Delta Deep Marine(5) El Manzala Offshore El Burg Offshore North Sidi Kerir Deep

4 8 1 1 1

294 1 355 914 1 463 1 949

Gas Gas Unknown Unknown Unknown

4 8 1 1 1

80 50 100 70 50

India(6)

Mid and South Tapti Panna/Mukta KG-OSN-2004/1

1 2 1

1 471 1 207 1 131

Gas Various Unknown

1 2 1

30 30 45

Israel

Med Yavne

1

52

Gas

1

35

Italy

Po Valley Permits (Italy Onshore)

6

3 944

Unknown

5

Various

Kazakhstan(7)

Karachaganak

1

280

Various

1

32.5

Libya

Sirte Block 123-1 Sirte Block 123-2 Kufra Blocks 171-01, 2, 3 & 4

1 1 4

2 753 2 144 11 305

Unknown Unknown Unknown

1 1 0

100 100 50

Madagascar

Majunga Offshore Profond

1

15 161

Unknown

1

30

Nigeria

OPL332 OPL286

1 1

1 258 804

Unknown Unknown

1 1

45 66

Norway

Southern North Sea North Tampen Mid-Norway Barents Sea

17 10 29 8

1 307 1 146 5 059 525

Oil & Unknown Unknown Unknown Unknown

13 8 14 2

Various Various Various Various

Oman

Block 60

1

1 485

Gas

1

100

Areas of Palestinian Authority

Gaza Marine

1

2 000

Gas

1

90

Thailand

2/2539/49(7) 3/2515/7 3/2549/71 4/2515/8(8) 5/2515/9

2 2 1 3 1

34 1 921 622 10 420 1 279

Various Various Various Unknown Various

0 0 0 3 0

22.22 22.22 22.22 50 22.22

Trinidad and Tobago

Block 5(a) Block 6(9) Block E Central Block NCMA-1

1 1 1 1 1

90 525 50 111 342

Various Various Gas Various Gas

1 1 1 1 1

50 50 50 65 57

Tunisia

Amilcar Miskar Ulysse Hasdrubal

1 1 1 1

1 016 320 2 812 260

Unknown Various Unknown Various

1 1 1 1

50 100 50 50

United Kingdom(7)

Southern North Sea Central North Sea Onshore

22 69 5

779 4 367 500

Gas & Unknown Various & Unknown Gas

18 34 0

Various Various 51

446

3 188 401

Unknown

0

37

United States(10)

Foothills & Eastern North Slope 2

The gross area figures given are approximations only. Gross area figures are in km unless otherwise indicated The type of field is given as Various where it relates to oil and/or gas and/or condensate or Unknown where the interest is an exploration interest with no discovery Figures given for Gross area are in hectares Rosetta Concession comprises 4 Development Leases (Rosetta Exploration Licence expired May 2003) West Delta Deep Marine Concession comprises 8 Development Leases (WDDM Exploration Licence expired Nov 2006). Applications for the re-shaping of Areas 1-4 and the grant of Area 5 are pending governmental approval (6) Jointly operated with ONGC and Reliance Industries (7) Includes part blocks (8) Area is subject to international boundary dispute – obligations under suspension pending resolution (9) Block 6, Manatee operated by Chevron Trinidad and Tobago Resources SRL (10) Figures given for Gross area are in acres

BG Group Data Book 2007

STATISTICAL SUPPLEMENT

(1) (2) (3) (4) (5)

Alaska

50

LNG Facilities capacity (mtpa) As at 31 July 2007

EXPORT TERMINALS Train

BG Group Equity/ Utilisation (%)

Total Capacity (mtpa) Gross

Total Capacity (mtpa) Net

Status

Atlantic LNG

1

26.00

3.1

0.806

Since April 1999

Atlantic LNG

2

32.50

3.4

1.105

Since April 2002

Atlantic LNG

3

32.50

3.4

1.105

Since April 2003

Atlantic LNG

4

28.89

5.2

1.502

Since December 2005

Egyptian LNG

1

35.50

3.6

1.278

Since May 2005

Egyptian LNG

2

38.00

3.6

1.368

Since September 2005

Total operating

7.164

IMPORT TERMINALS Total Capacity (mtpa) Gross

Lake Charles, USA

Total Capacity (mtpa) Net

13.4

13.4

4.2(1)

Elba Island, USA

4.2(1)

Bcfd Net

Status

1.80

100% since 1 January 2004 Phase 2 expansion completed July 2006

0.57

100% since 1 January 2004 Elba Cypress pipeline debottlenecking since May 2007

Total operating

17.6

17.6

2.37

Lake Charles IEP

3.9

3.9

0.55

Total planned expansions

3.9

3.9

0.55

In development: Dragon LNG, Milford Haven, Wales

4.4

2.2

0.30

Anticipated end 2007

2.5(2)

0.0

0.00

Anticipated 2009/2010

6.0

4.8(3)

GNL Quintero, Chile Brindisi, Italy

Anticipated 2008

0.65

Anticipated end 2010

Elba Island, USA

4.3

4.3

0.60

Anticipated in service 2014

Total in development

17.2

11.3

1.55

(1) (2) (3) (4)

(4)

Of which 1.2 mtpa may be utilised by Marathon BG Group currently holds no terminal capacity in the terminal currently under construction but has the option to acquire capacity if needed to support BG Group’s downstream market development BG Group has 80% access. The remaining 20% is for third-party access Reflects BG Group held capacity only

LNG: Long-term firm supply(1) Firm Supply (mtpa)

Atlantic LNG T2/3 Nigeria LNG T4/5

Commercial start-up

2.1

2003

2.3

Q1 2006

Egyptian LNG T2(2) Atlantic LNG T4(3)

3.5

Q2 2006

1.5

Q2 2007

Equatorial Guinea(4)

3.3

Q3 2007

Nigeria LNG T7(5)

2.3

2012

Total firm supply

15.0

(1) (2) (3) (4) (5)

Assumes delivery into US East Coast First cargo lifted in September 2005 First cargo lifted in January 2006 First cargo lifted in May 2007 First cargo expected 2012

LNG Cargoes Q2 2007

Q1 2007

Year 2006

Q4 2006

Q3 2006

Q2 2006

Q1 2006

Year 2005

46

18

50

17

15

54

12

14

15

16

8

19

78

23

71

52

182

Sales volumes Re-marketed

184

92

25

53

Total managed volumes

209

145

Q4 2005

Q3 2005

22

2

36

11

8

14

9

50

14

15

13

13

29

31

13

7

50

43

49

40

117

38

289

74

88

97

30

238

223

66

39

32

86

92

512

140

127

129

116

330

109

Q2 2005

Q1 2005

Year 2004

Q4 2004

Q3 2004

Q2 2004

Q1 2004

9

8

11

10

59

8

23

16

12

41

11

12

10

1

8

10

18

7

8

2

30

1

21

28

118

26

43

28

21

70 39

63

56

49

276

57

92

77

50

20

3

30

53

20

24

6

3

83

59

79

329

77

116

83

53

Actual Cargoes Lake Charles Elba Island Re-marketed Total Managed volumes (trillion British thermal units)

BG Group Data Book 2007

LNG Ships

51

AS AT 31 JULY 2007 Name

Year built

Capacity (bcm)(1)

Propulsion

Containment

Contract

Core fleet

Methane Alison Victoria

2007

145 127

ST(2)

Mk.III

BB(3)

(5+ years)

Methane Heather Sally

2007

145 127

ST

Mk.III

BB

Methane Shirley Elisabeth

2007

145 127

ST

Mk.III

BB

Methane Jane Elizabeth

2006

145 127

ST

Mk.III

BB

Methane Lydon Volney

2006

145 127

ST

Mk.III

BB

Methane Rita Andrea

2006

145 127

ST

Mk.III

BB

Methane Kari Elin

2004

138 200

ST

Mk.III

BB

Methane Princess

2003

137 990

ST

No.96

TC(4)

8

1 146 952

Subtotal Additional

Neo Energy

2007

149 700

ST

Mk.III

TC

(0-5 years)

Seri Anggun

2006

145 000

ST

Mk.III

TC

Seri Alam Gracilis

2005

145 000

ST

Mk.III

TC

2005

137 000

ST

Mk.III

TC

Granatina Tenaga Empat

2003

140 500

ST

No.96

TC

1981

130 000

ST

No.88

TC

Golar Freeze Khannur(5)

1977

125 856

ST

Moss

TC

1977

125 016

ST

Moss

TC

Gimi Hilli

1976

124 886

ST

Moss

TC

1975

124 872

ST

Moss

TC

Subtotal

9

1 222 814

Total

17

2 369 766

New builds

Methane Nile Eagle

2007

145 127

Mk. III

TC

SHI HN 1607 SHI HN 1626

2008

165 500

DFDE(6)

Mk. III

TC

2009

165 500

DFDE

Mk. III

TC

2009

170 000

DFDE

Mk. III

Owned

2010

170 000

DFDE

Mk. III

Owned

5

816 127

SHI HN 1745 SHI HN 1746 Total (1) (2) (3) (4) (5) (6)

ST

Capacity – gross 100% ST – steam turbine BB – bareboat charter TC – time charter Khannur – sub-chartered DFDE – dual-fuel diesel-electric

Transmission and Distribution As at 31 December

Throughput (million cubic metres per year) Net to BG Group Customers Comgas MetroGAS Gujarat Gas

2006

2005

2004

11 925

13 199

13 383

516 000

484 144

454 285

2 000 000

2 000 000

1 969 794

248 000

200 000

162 479

Power

AS AT 31 JULY 2007 CAPACITY Name

Italy Malaysia Philippines

Serene S.p.A.(1) Genting Sanyen Power (Kuala Langat) First Gas Power (San Lorenzo)

Philippines UK

First Gas Power (Santa Rita) Premier Power (Ballylumford)

UK USA

Seabank Power Dighton(4)

USA USA

Lake Road(2) (4) Masspower(3) (4)

Cogen – secured capacity

Brazil & India

Total operational (1) (2) (3) (4)

BG Group Equity (%)

Operating Total (MW)

Operating Net to BG Group (MW)

100

386

386

20

760

152

40

505

202

40

1 000

400

100

1 316

1 316

50

1 130

565

100

165

165

100

785

785

100

264

264

–

65

59

6 376

4 294

Agreement announced in 2006 to acquire remaining equity in Serene S.p.A., completed February 2007 Agreement announced in 2006 to acquire Lake Road power plant, completed March 2007 Masspower plant acquired May 2007 ISO-NE weighted average annual installed capacity ratings BG Group Data Book 2007

STATISTICAL SUPPLEMENT

Location

52

Principal acquisitions, commitments and divestments ACQUISITIONS (TO 31 JULY 2007) Announced

Details

Completion

£m

2007 April

Acquired Masspower 262 MW power plant, USA Acquired further 11.45% in Armada and 1.0134% in Everest fields, UKCS

May 2007

74

March 2007

67

2006 December September

Acquired Lake Road 805 MW power plant, USA

March 2007

351

Acquired further 66.32% stake in Serene S.p.A. power plants, Italy

February 2007

80

Acquired Dighton 175 MW power plant, USA

October 2006

47

June 2005

29

November 2004

120

July 2004

13

2005 June

Acquired remaining 50% in Brindisi LNG import terminal, Italy

2004 September

Acquisition of further 40% stake in Rosetta, Egypt

May March

Acquisition of exploration block offshore Brazil Acquisition of DirectNet

March February

Acquisition of Aventura Energy Inc Acquisition of El Paso Oil and Gas Canada Inc

February

Acquisition of Mauritania Holdings B.V.

March 2004

(1)

April 2004

5

May 2004

92

March 2004

189 74(1)

Includes US$5.1 million contingencies

COMMITMENTS (TO 31 JULY 2007) Announced

Details

Completion

£m

2007 Exercised options to purchase two new LNG ships

2009/2010 delivery

Exercised options to purchase four new LNG ships

2007 delivery

2004 April

349

2003 December October (2)

Acquired LNG supply, regas capacity and customers at Elba Island, Georgia, USA Exercised options to purchase three new LNG ships

January 2004

72(2)

Second half 2006 delivery

270

Completion

£m

Of which US$50 million is deferred and conditional

DIVESTMENTS (TO 31 JULY 2007) Announced

Details

2007 May

Sale of entire 25% stake in Interconnector (UK) Limited

June 2007

165

March

Sale of producing assets in Canada – Bubbles, Ojay and Copton/Lynx

April 2007

228

January

Sale of Mauritania interests

January 2007

68

2006 Sale of 37.5% interest in NVGC June

November 2006

4

Sale of India Telecoms

June 2006

1

Sale of Brazil Telecoms

November/December 2005

11

March 2005

26

January 2004

32

2005(3) March

Sale of entire 50% interest in Premier Transmission Ltd

2004 1.21% in Gas Authority of India Ltd 2003 December November

Sale of 50% interest in Muturi PSC and related 10.73% interest in the Tangguh LNG project, Indonesia Sale of 51% interest in Phoenix Natural Gas

April March

Sale of package of North Sea assets Sale of entire 16.67% interest in the North Caspian PSA

(3)

May 2004

142

December 2003

120

September 2003

72

April 2005

936

In December 2005, on signing a Master Restructuring Agreement with the other shareholders and creditors of Gas Argentino S.A., parent company of MetroGAS S.A., BG Group ceased to control these companies and deconsolidated them from that date

Credit Ratings (BG Energy Holdings Ltd) BG Energy Holdings Ltd (BGEH) is rated by three major credit rating agencies: Rating agency

Fitch Moody’s Standard & Poor’s

Long-term rating

Date assigned

A

August 2005

Stable

A2

August 2005

Stable

A-

June 2002

Stable

BGEH’s objective is to achieve long-term credit ratings equivalent to mid-single A from all the above agencies

BG Group Data Book 2007

Outlook

Corporate information

53

TOTAL ISSUED ORDINARY SHARE CAPITAL Shares in issue at year end (millions)

2006

2005

2004

3 464

3 549

3 536

DIVIDEND DATA Payment

Value

Announcement Date

Ex-dividend Date

Record Date

Payment Date UK

Final

1.45p

15 February 2001

25 April 2001

27 April 2001

8 June 2001

18 June 2001

Interim

1.50p

26 July 2001

24 October 2001

26 October 2001

14 December 2001

24 December 2001

Final

1.50p

21 February 2002

24 April 2002

26 April 2002

7 June 2002

17 June 2002

Interim

1.55p

25 July 2002

23 October 2002

25 October 2002

13 December 2002

23 December 2002

Final

1.55p

18 February 2003

19 March 2003

21 March 2003

2 May 2003

12 May 2003

Interim

1.60p

28 July 2003

6 August 2003

8 August 2003

12 September 2003

19 September 2003

Final

1.86p

17 February 2004

14 April 2004

16 April 2004

28 May 2004

7 June 2004

Interim

1.73p

28 July 2004

4 August 2004

6 August 2004

10 September 2004

17 September 2004

Final Interim

2.08p

15 February 2005

30 March 2005

1 April 2005

13 May 2005

20 May 2005

1.91p

27 July 2005

10 August 2005

12 August 2005

16 September 2005

23 September 2005

Final Interim

4.09p

8 February 2006

29 March 2006

31 March 2006

12 May 2006

19 May 2006

3.00p

24 July 2006

9 August 2006

11 August 2006

15 September 2006

22 September 2006

4.20p

8 February 2007

11 April 2007

13 April 2007

25 May 2007

4 June 2007

3.60p

27 July 2007

8 August 2007

10 August 2007

14 September 2007

21 September 2007

Final Interim

Payment Date USA

INVESTOR CALENDAR Event

Type

Date

Presentation

8 February 2007

2007 Q4 and Full Year 2006 Results and Strategy Presentation 2006 Final dividend 2007 Annual General Meeting Q1 2007 Results 2006 Final dividend Q2 2007 Results 2007 Interim dividend 2007 Interim dividend Q3 2007 Results

Ex-dividend

11 April 2007

Meeting

14 May 2007

Announcement

4 May 2007

Dividend Paid (UK)

25 May 2007

Dividend Paid (USA ADR)

4 June 2007

Announcement

27 July 2007

Ex-dividend

8 August 2007

Dividend Paid (UK)

14 September 2007

Dividend Paid (USA ADR)

21 September 2007

Announcement

1 November 2007

Presentation

February

2008 Q4 and Full Year 2007 Results and Strategy Presentation 2007 Final dividend 2008 Annual General Meeting Q1 2008 Results 2007 Final dividend

April(1)

Meeting

May(1) (1)

Announcement

Q2 2008 Results 2008 Interim dividend 2008 Interim dividend Q3 2008 Results (1)

Ex-dividend

May

Dividend Paid (UK)

May(1)

Dividend Paid (USA ADR)

May(1)

Announcement

July(1)

Ex-dividend

August(1)

Dividend Paid (UK)

September(1)

Dividend Paid (USA ADR)

September(1)

Announcement

November(1)

Provisional dates

Stock Exchange Information

American Depositary Receipts

Lloyds TSB Registrars The Causeway, Worthing West Sussex BN99 6DA

London Stock Exchange Ticker symbol: BG.L SEDOL number: 876289

ADR Depositary, JPMorgan Chase Bank JPMorgan Service Center, PO Box 3408, South Hackensack, NJ 07606-3408, USA

New York Stock Exchange Ticker symbol: BRG.N

+1 800 990 1135 (US toll-free) +1 201 680 6630 (outside USA)

One ADR: 5 ordinary shares Cusip number: 55434203

www.adr.com/shareholder Email: [email protected]

Tel: 0870 600 3951 www.shareview.co.uk Email: [email protected]

BG Group Data Book 2007

STATISTICAL SUPPLEMENT

Registrars

54

Definitions For the purpose of this document the following definitions apply: $

US dollar

mmbbls

Million barrels

£

UK pounds sterling

mmboe

Million barrels of oil equivalent

bbls

Barrels

mmbopd

Million barrels of oil per day

bcf

Billion cubic feet

mmcmd

Million cubic metres per day

bcfpd

Billion cubic feet per day

mmscm

Million standard cubic metres

bcm

Billion cubic metres

mmscmd

Million standard cubic metres per day

bcma

Billion cubic metres per annum

mmscf

Million standard cubic feet

bcpd

Barrels of condensate per day

mmscfd

Million standard cubic feet per day

BG Group

BG Group plc or any of its subsidiary undertakings, joint ventures or associated undertakings

MoA

Memorandum of Agreement

MoU

Memorandum of Understanding

billion or bn

One thousand million

mtpa

Million tonnes per annum

boe

Barrels of oil equivalent

MW

Megawatt

boed

Barrels of oil equivalent per day

MWh

Megawatt hours

bopd

Barrels of oil per day

NGL

Natural Gas Liquids

bpd

Barrels per day

NGV

Natural Gas Vehicle

Btu

British thermal units

normal bcm

CAGR

Compound Average Growth Rate

Billion cubic metres of gas at zero degrees Celsius and at an absolute pressure of 1.01325 bar

CCGT

Combined Cycle Gas Turbine

PSC/PSA

CNG

Compressed Natural Gas

Production Sharing Contract/Production Sharing Agreement

cm

Cubic metre

partner

DCQ

Daily Contracted Quantity

DTI

Department of Trade and Industry

EPC

Engineering Procurement Construction

FEED

Front End Engineering Design

GSA

Gas Sales Agreement

An entity with whom BG Group has formed an incorporated or unincorporated association or joint venture for the purposes of pursuing its business activities and the term “partner” in this context is not intended to, nor shall be deemed to, create or constitute a partnership between BG Group and any such entity for the purposes of the Partnership Act 1890 or any similar law in any jurisdiction in which such activities may be conducted

GW

Gigawatts

PPA

Power Purchasing Agreement

GWh

Gigawatt hours

SPA

Sale and Purchase Agreement

HIIP

Hydrocarbons Initially In Place

sq km

Square kilometres

HPHT

High Pressure High Temperature

tcf

Trillion cubic feet

km

Kilometres

BG Group Data Book 2007

Index of assets Page EXPLORATION AND PRODUCTION FIELDS, BLOCKS, TERMINALS, CONCESSIONS AND LICENCES Alaska Foothills and eastern North Slope 32 Algeria Hassi Ba Hamou Perimeter

29

Bolivia Block XX Tarija East and West Caipipendi Charagua Itau La Vertiente Los Suris Margarita Palo Marcado Ibibobo-Mistol

16 16 16 15 16 16 15 16 16

Brazil BM-S-9, 10, 11 and 13 BM-S-47, 50, 52 BT-SF-2 Tupi

17 17 17 17

Canada Deep West area of the Western Canada Sedimentary Basin Foothills Northwest Territories Waterton China Blocks 64/11, 53/16 and 41/06 Egypt El Burg and El Manzala Mina and Silva North Sidi Kerir Deep Rosetta Scarab Saffron Simian, Sienna and Sapphire Solar, Serpent, Saurus, Sequoia and Sienna-Up West Delta Deep Marine (WDDM) India Panna/Mukta and Tapti Israel and areas of Palestinian Authority Med Yavne Gaza Marine

Page Oman Block 60

32 32 32 32 21 26 26 26 26 26 26 26 26 19

24 23

UK Dragon LNG

5

USA Elba Island Lake Charles Providence

37 36 37

Thailand Bongkot Gulf of Thailand Blocks 7, 8, 9 and 9A

23

Trinidad and Tobago Block 5(a) Block 6(b) and 6(d) Block E Central Block Chaconia Dolphin and Dolphin Deep East Coast Marine Area (ECMA) Hibiscus Ixora Loran/Manatee North Coast Marine Area (NCMA) Poinsettia

33 33 33 34 34 33 33 34 34 33 34 34

Tunisia Amilcar Hasdrubal Miskar Ulysse A & B Hannibal

31 31 31 31 31

UK and Faroe Islands Amethyst Armada Apollo Atlantic/Cromarty Blake and Blake Flank Buzzard Drake Easington Catchment Area (ECA) Elgin/Franklin and Glenelg Everest and Lomond Fleming Hawkins J-Block, Jade, Judy/Joanne Jackdaw Jasmine Maria Mercury, Minerva and Neptune SW Seymour and NW Seymour Whittle and Wollaston

6 6 8 7 7 7 6 8 8 8 6 6 9 9 9 9 8 6 8

LIQUEFIED NATURAL GAS 28 28

Italy Po Valley

11

Kazakhstan Karachaganak

12

Libya Area 123 and Area 171

29

Madagascar Majunga Offshore Profond

29

Norway Bream

10

Nigeria OPL 332 and OPL286-DO

30

Page Chile GNL Quintero

LIQUEFACTION TERMINALS Egypt Egyptian LNG Trains 1 and 2

26

Nigeria OKLNG

30

Trinidad and Tobago Atlantic LNG Trains 1, 2, 3 and 4

35

REGASIFICATION TERMINALS Italy Brindisi LNG

11

16

TRANSMISSION South America Bolivia – Brazil Pipeline Southern Cross and Gas Link Pipelines

17 14

Kazakhstan Caspian Pipeline Consortium (CPC)

13

UK CATS Interconnector UK SEAL and SILK

9 4 9

DISTRIBUTION Argentina MetroGAS

14

Brazil Comgas Iqara Gas Natural

18 18

Egypt Nile Valley Gas Company (NVGC)

27

India Gujarat Gas Company (GGCL) Mahanagar Gas (MGL)

20 20

POWER Italy Serene S.p.A.

11

Malaysia Genting Sanyen

21

Philippines San Lorenzo Santa Rita

22 22

UK Premier Power (Ballylumford) Seabank USA Dighton Lake Road Masspower

4 4 38 38 38

Further information A decade of delivery

Further information on BG Group can be found in the 2006 Annual Report and Accounts, and the 2006 Corporate Responsibility Report on www.bg-group.com

BG Group Annual Report and Accounts 2006

www.bg-group.com

Annual Report and Accounts 2006

BG Group plc 100 Thames Valley Park Drive Reading, Berkshire RG6 1PT www.bg-group.com Registered in England & Wales No. 3690065 Designed and produced by Black Sun plc. Printed by Butler and Tanner.

Working responsibly

BG Group Corporate Responsibility Report 2006

Corporate Responsibility Report 2006

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