1 Deepsea Metro I drillship

Tanzania

2012 results presentation 5 February, 2013

2

Welcome

LNG storage tank Curtis Island, Australia

Andrew Gould Chairman

Legal notice

The following presentation contains forward-looking statements concerning BG Group plc’s strategy, operations, financial performance or condition, outlook, growth opportunities or circumstances in the countries, sectors or markets in which BG Group plc operates. By their nature, forward-looking statements involve uncertainty because they depend on future circumstances, and relate to events, not all of which can be controlled or predicted. Although the Company believes that the expectations reflected in such forward-looking statements are reasonable, no assurance can be given that such expectations will prove to have been correct. Actual results could differ materially from the guidance given in this presentation for a number of reasons. For a detailed analysis of the factors that may affect our business, financial performance or results of operations, we urge you to look at the “Principal risks and uncertainties” included in the BG Group plc Annual Report & Accounts 2011 and at the Principal Risks section later in this presentation. Nothing in this presentation should be construed as a profit forecast and no part of this presentation constitutes, or shall be taken to constitute, an invitation or inducement to invest in BG Group plc or any other entity, and must not be relied upon in any way in connection with any investment decision. BG Group plc undertakes no obligation to update any forward-looking statements.

No representation or warranty, express or implied, is or will be made in relation to the accuracy or completeness of the information in this presentation and no responsibility or liability is or will be accepted by BG Group plc or any of its respective subsidiaries, affiliates and associated companies (or by any of their respective officers, employees or agents) in relation to it.

Please note that this presentation represents only a summary of BG Group’s Fourth Quarter and Full Year Results for the financial year ended 31 December 2012. It does not contain sufficient information to enable as full an understanding as provided by the BG Group Fourth Quarter and Full Year Results for 2012 and the transcript of the speech given by the Chief Executive and Interim Chief Financial Officer of BG Group that accompany this presentation. This presentation should therefore be read in conjunction with those additional documents available from BG Group’s website, www.bg-group.com.

3

FPSO 2 Cidade de São Paulo departure Brazil

Chris Finlayson Chief Executive

Introduction

Strategic intent

• Strategy will build on BG Group’s distinctive strengths

– World class exploration

– Unique LNG model

– Commercial agility

• Focused portfolio

– Continual active review

• Industry leading growth in shareholder value

– Significant volume & cash flow growth in 2014 & 2015

5

Priorities for 2013

• Relentless focus on safety

• Production delivery in our base assets, in particular Egypt & UK

• Delivery of key projects with clear quarterly milestones

– In Brazil having a third producing FPSO vessel onstream in Q2

– In Australia having first gas to start commissioning QCLNG around year end

– 7 major projects onstream

• Continued emphasis on exploration: increased budget to $1.6 bn

• Tight cost management

• Completion of current portfolio rationalisation programme

6

7 Main pipeline network

Narrows crossing, Queensland, Australia

Full year results Den Jones Interim Chief Financial Officer

Reporting segment changes

8

E&P Liquefaction Shipping & Marketing T&D

Upstream LNG Shipping & Marketing

Old segment split

New segment split

T&D discontinued

E&P LNG T&D

Financial highlights: Q4 2012

9

Q4 2012

Q4 2011 Δ YOY

Upstream

LNG Shipping & Marketing

Cash generated by operations

Total operating profit

$1 169m $1 334m -12%

$658m $784m -16%

$2 248m $2 655m -15%

$1 831m $2 089m -12%

Earnings $1 030m $1 456m -29%

Upstream segment includes E&P and liquefaction activities

* Q4 2011 restated to exclude $277m one-off tax credit

Underlying earnings* $1 030m $1 179m -13%

Financial highlights: 2012

10

2012 2011 Δ YOY

Upstream

LNG Shipping & Marketing

Cash generated by operations

Total operating profit

$5 464m $5 440m -

$2 577m $2 282m +13%

$10 715m $9 773m +10%

$8 047m $7 732m +4%

Earnings $4 395m $4 251m +3%

Dividend per share 26.14 cents 23.76 cents +10%

Upstream segment includes E&P and liquefaction activities

352 334

158

534

18

5149 5118

291 346

0

2000

4000

6000

8000

2011 Volume Price Opex DD&A Other 2012

E&P

Liquefaction Liquefaction

E&P

5440 5464

Upstream operating profit

11

Year on year Upstream operating profit change ($m)

12

E&P unit cost performance

12

Annual unit DD&A cost ($/boe)

BG Group Peer Group includes Super Majors and US and European Integrated Majors Source (2009-2011): Evaluate Energy 2012

0 10 20

Annual unit opex cost ($/boe)

0 20 40

Peer 2011

BG Group 2012 BG Group 2011

Peer 2011

BG Group 2012 BG Group 2011

176%

217%

0%

50%

100%

150%

200%

250%

1 year SEC proved RRR

3 year SEC proved RRR 0% 100% 200% 300%

13

Strong reserves replacement

13

BG Group 2009-2011

Peer 2009-2011

BG Group 2010-2012

Peer group includes Super Majors and US and European Integrated Majors

3 year total reserves replacement

Source: Evaluate Energy 2012

BG Group’s reserves replacement

2923 217 512

2282

2577

0

1000

2000

3000

2011 Margin & Mix Shipping 2012 Old LNG segment

Year on year LNG Shipping & Marketing operating profit change ($m)

LNG* operating profit

14

Liquefaction

* LNG Shipping & Marketing

15

5.7 5.6

6.2 6.1

1.5 1.0

0

5

10

15

2011 2012

1.8 1.3

6.8 7.7

2.7 2.6

1.5 0.5

0.6 0.6

0

5

10

15

2011 2012

Sources loaded (mtpa) Destinations delivered (mtpa)

Operated production

Long-term third-party purchases

South America

USA

Asia

Europe

Ship use 13.4

12.7

Long-term contracts (11.6 mtpa)

Short-term third-party purchases

13.4 12.7

LNG sources and destinations

Sales volume (12.1 mtpa)

2013 LNG outlook

16

• 11.3 mtpa of LNG volumes* from our long-term contracted supply

– Reduction of 0.3 mtpa from 2012 principally due to Egypt

– Minimal spot volumes

• Singapore LNG to start commercial operations in Q2 2013

• Portfolio substantially unhedged

• Chile has switched to a predominantly HH linked basis

• Operating profit LNG shipping & marketing $2.5-2.7 bn**

– Equivalent to LNG operating profit of $2.9-3.1 bn** on old segment basis

* Loaded volumes

** At current market conditions

10.7

2.9

0.6 1.2

10.4

2.7

1.4

0

4

8

12

16

Sources Uses

2012: sources and uses of funds

17

• Net cash inflow of $0.9 bn

– Net additional borrowings of $1.2 bn

– Net cash outflow $0.3 bn before borrowings

• Capital investment: $10.4 bn (cash basis)

• 94% cash disbursements self-funded

– Strong operating cash flow

– $2.9 bn through sale of non-core businesses

($bn)

15.4 14.5

Other

Operating cash flow

Disposals

Borrowings

Tax

Capex

Dividends & interest

2012-13: cash capex split

18

5.0 5.5

1.6

2.7

2.7

3.0 1.1

0.8 0.8 0.3

0

5

10

15

2012 Q1 guidance Australia Other 2012 2013

10.4

12.0

Base assets

Australia*

Other

Brazil

11.5

($bn)

* 2013 cash capex in Australia assumes the part disposal of the QCLNG project to CNOOC completes in mid-2013

Base assets includes Bolivia, Egypt, India, Kazakhstan, Norway, Thailand, Trinidad and Tobago, Tunisia, UK

Portfolio rationalisation progress

• Portfolio refocused to E&P and LNG

• Capital release of $8.1 bn by end 2013

• Significantly exceed $5 bn target

• Key milestones in Q4

– QCLNG sell-down: HOA signed

– Comgás disposal: completed

– Gujarat Gas disposal: SPA signed

– Quintero LNG disposal: part completed

– Bolivia-Brazil pipeline disposal: SPA signed

– BG Italia Power disposal: completed

– MetroGAS disposal: SPA signed

19

3.8

8.1

4.3

0

5

10

2012 2013

Total capital release ($bn)

End 2013 target

Completed Agreed*

* Includes $0.5bn of cash capex saving in 2013

Financial structure & liquidity

20

0%

10%

20%

30%

0

1000

2000

3000

4000

5000

2010 2011 2012

• Maintain a robust financial structure

• Gearing fell from 27% to 24% (2011-12)

– Cash balance increased to $4.4 bn

• Diversifying & extending funding sources

– Average gross debt maturity up to 17 years

– Cash & undrawn committed bank facilities: $9.6 bn

Cash ($m) and gearing (%)

Gearing Cash balance

Armada UK

Excellence in execution

0.0

0.5

1.0

1.5

2.0

2.5

2008 2010 2012

2012 safety performance

22

• Two fatalities in 2012

– Lessons learned shared around Group

• Majority of Group** met TRCF target

– Top quartile performance***

• QGC missed target

– Improving contractor management

• Focus on process safety & asset integrity

Group

Group excluding QGC

2012 Group target

TRCF* (per million work hours)

*Total recordable case frequency (includes employees & contractors working on operated assets)

** Excludes QGC *** OGP industry benchmark 2011

Top Quartile***

Industry Average***

-30

-20

-10

0

10

Kaz

akhs

tan

Trin

idad

Thai

land

Indi

a

Tuni

sia

Nor

way

Bol

ivia

Egy

pt

UK

23

• 2012 base asset production

– Majority producing close to expectations

• 2008-12 (excluding UK and Egypt)

– 550 mmboe produced

– 89% production efficiency

– No production decline (post-investment)

• UK and Egypt

– Major driver of production shortfall

Variance to 2012 budget (kboed)

Base asset production performance

24

0%

25%

50%

75%

100%

0

40

80

120

160

2008 2010 2012

• Two producing assets (Rosetta & WDDM)

• Rosetta producing to plan

• WDDM

– Good production efficiency of >90%

– Recent decline due to water breakthrough

• 2012 WDDM development phase

– 9 new wells & compression

– Added production

– Wells performed close to expectations

– Higher water production & lower gas volumes

Egypt: WDDM production performance

Production (kboed) & PE* (%)

WDDM Budget WDDM PE%

* Production efficiency

• Improve predictability of field performance

• Increase production from existing well stock

– Workovers & acid stimulations

• Sanctioned next phase of WDDM development subject to partner approval

– Commence drilling Q2 2013

– Onstream in 2014

– Plan for 18 new development wells (2 tcf gross)

• Target near field exploration prospects close to existing infrastructure

– 2 exploration wells in 2013

• Production decline until new development wells onstream in 2014

25

Egypt: WDDM recovery plan

UK: production performance

• Significant value 2008-2012

– ca $12 bn operating profit

– Added ~200 mmboe of reserves & resources

• Non-operated assets; 2/3 of 2012 shortfall

– Elgin/Franklin well integrity: 45% of shortfall

– Buzzard shut-down extended

• Operated assets

– Limited accommodation

– Safety critical maintenance carried out

– Unable to complete all maintenance improvements to fully recover PE in 2012

26

0%

25%

50%

75%

100%

0

50

100

150

200

2008 2010 2012

UK other Elgin hub

UK other PE%

Budget

Elgin hub PE%*

Production (kboed) & PE (%)

* Elgin/Franklin PE @ full year 2012

UK: improving production efficiency

• Armada; step change in maintenance

– PE increased to 82% over 4 years

• Applying Armada knowledge

– Maintenance campaigns: Everest & Lomond

– Flotels to provide additional accommodation

– Significant reserves & development potential

– Working closely with Buzzard operator

• 2013 production higher than 2012

27

Buzzard platform UK

2013 production outlook

• 7 projects coming onstream

• Elgin/Franklin restart

• Growth projects offset by

– Strategic decision to lower production in US

– Natural decline in Egypt

– Maintenance shutdown in Karachaganak

– Reduced equity in QCLNG

• 2013 production outlook: 630-660 kboed

28

Q2 Brazil FPSO 3 onstream Karachaganak planned shutdown

Q3 Bongkot N Ph 3K onstream Itau Ph 2 onstream UK shutdowns

Q1 Brazil FPSO 2 onstream Everest East expansion onstream Elgin/Franklin production restart

Quarterly milestones

✓

Q4 Jasmine onstream Margarita Ph 2 onstream

Kenya water treatment plant Australia

Excellence in execution

30

Current status

Wells 148 drilled Q4 2012, total 1160

New field compressor stations (FCS) 2 operating, 6 under construction

Ruby central processing plant 25% complete, all compressors delivered

Gas collection header 100% welded, 75% in the ground, crossing and tie-ins progressing

Export pipeline 74% welded, 45% in the ground

Narrows crossing 50% welded, dredging complete

LNG modules 24 on Curtis Island, further 25 in transit from Thailand

Good progress on QCLNG

Upstream

Pipeline*

LNG

* Progress percentages apply to mainline pipelines and exclude crossings / tie-ins

2013 2014

Q1 Q2 Q3 Q4 H1 H2

Ups

tream

P

ipel

ine

LNG

QCLNG on track for 2014 LNG sales

31

First major water facility (Kenya)

Central processing plant (Ruby)

Six FCSs (for Ruby)

Gas collection header

Export pipeline

Narrows crossing

Modules delivered*:

LNG sales

Gas in plant - start commissioning

>2000 wells 1750 1600 1450 Wells: 1290

T1 & common facilities T2

* 80 modules in total (62 for train 1 and common facilities)

• Two-train project 51% complete*

• Scope to fill 1st train >60% complete

• Contracts & other agreements: 94%

• Project on schedule

• Confident in $20.4 bn budget (2011-14)

32

QCLNG on budget

* Value of work done

Tank construction, QCLNG Curtis Island, Australia

33

• Exceptional reservoir performance

– Production to date >65 mmboe (gross)

– Reserves & resources: 4-6-8 bn boe*

• FPSOs increased from 13 to 15

– ca 2.5 mmboed capacity by 2018

• Strong project execution

– 18 wells drilled & 21 well tests completed

– Up to 12 rigs drilling simultaneously

– 2 EWTs performed

– Sapinhoá commercial production (FPSO 2)

– FPSO 3 on schedule for Q2 2013

• Costs on track within budget

– 2012: gross capex commitments $14.3 bn

* Independently certified report commissioned by BG Group, not the view of the operator or relevant consortia

FPSO 2 Santos Basin, Brazil

Brazil: good progress

FPSO 1 performing better than expected

• 50 mmboe gross production to date

• Sustained exceptional well deliverability

– >20 mmboe from single well

– >100 kboed from 4 wells

– 1st horizontal producer onstream Q2 2013

• 1st water alternating gas injector online

– Water injection started October 2012

– Pressure support from water injection

– Switch to gas injection in Q1

– 2nd water alternating gas injector: Q1 2013

34

FPSO Cidade de Angra dos Reis Santos Basin, Brazil

35

Continuously improving execution

• Large number of FPSOs and wells

– Continuous improvement as processes are repeated

• Wells: ~50% capex

– ~25% reduction in drill times* in 2012

– Potential for further cost reduction

– >100 Christmas trees contracted

• FPSOs: ~20% of capex

– Flexibility to add FPSOs to secure schedule & expand project scope

• Confidence in delivering projects on schedule & budget

* Spud to total depth

36 Deepsea Metro I drillship

Tanzania

Exploration

Continued E&A success in 2012

• 18 out of 19 E&A wells were successful

• Delivered additional 800 mmboe of discovered resources

• Matured 350 mmboe of resources to reserves

• Tanzania ca 10 tcf gross including giant Jodari discovery

• Iara appraisal confirmed previous estimates, volumes in place similar to Lula

• Australia successfully tested Bowen coal seam gas & deep gas sands plays

• Prospect inventory grown by 21%

– 4.6 bn boe net risked resources

– New licences acquired in Uruguay, Trinidad and Tobago, India & Egypt

37

Exploration in 2013

• Key wells

– Exploration: Egypt (Notus), Brazil (Sagittario), UK HPHT (Thunderer & Jade S)

– First Kenya well around year end

– Appraisal: Australia plays & Tanzania

– Iara: 2 appraisal wells; test well designs for field development

• Major seismic programmes

– Uruguay, Kenya, Tanzania, Egypt

• Sign new licences (gross 44000 sq km)

– Honduras, Bolivia, Norway & UK

38

Algeria

Bolivia

Global 2013 E&A operations

Egypt 2 wells

1-2 wells

Tanzania 1 well

1-2 wells

Brazil 3 wells 1 well

Australia 30-40 wells

2 wells

Kenya 1 well

Thailand 9 wells

UK 3 wells

USA 2-3 wells

Appraisal / near term production

New plays Play extenders

SEC Proved Reserves Probable Reserves* Discovered Resources** Risked Exploration

Total reserves & resources (mmboe)

2459 2600 2893 3247 3431

3383 3530 3823 3939 3758

3722 4931

5757 6160 6739

3562 3433

3707 3784

4583

0

5000

10000

15000

20000

2008 2009 2010 2011 2012

13126 14494

16180 17130

18511

Total reserves & resources

39 *Adopted SEC definition for Probable reserves in 2009; Discovered resources called Unbooked resources until 2009

Total reserves & resources as at year end

Summary

• Significant milestones to deliver in 2013

– Major growth assets & base assets

• Australia & Brazil are on budget and schedule

– Significant volume & cash flow growth in 2014 & 2015

• Exploration remains core to our strategy

– Significant E&A programme in 8 countries

• Strategy & longer term outlook beyond 2013 in May

40

41 Deepsea Metro I drillship

Tanzania

2012 results presentation 5 February, 2013

REFERENCE CONDITIONS • Brent Oil price real (1/1/2013): 2013: $100/bbl • US Henry Hub real (1/1/2013): 2013: $3.5/mmbtu • US/UK exchange rates of $1.6:£1 • US/AUD exchange rates of $1:$A1 • US/BRL exchange rates of $1:BRL1.90 • Prepared under International Financial Reporting Standards • All production includes fuel gas PRINCIPAL RISKS • Major recession, significant political upheaval or terrorist attacks in the major markets in which we operate • Failure to ensure the safe and secure operation of our assets worldwide • Operational performance including shut-down, asset integrity, natural hazards, reservoir and well performance • Implementation risk, being the challenges associated with delivering capital intensive projects on time and on budget

Commodity risk, being the risk of significant fluctuation in oil and/or gas prices from those assumed • Foreign exchange risk, exchange rates maybe being significantly different to those assumed • Interest rate, liquidity and credit risk • Technical, environmental, commercial, economic, legal, litigation, regulatory, political and country risk • Risks associated with successful discoveries, estimation, appraisal and development of reserves

42

For a detailed discussion of these and other risk factors, please refer to the Principal risks and uncertainties included in BG Group’s Annual Report and Accounts .

Actual performance could differ materially from that shown. Accordingly, no assurances can be given that such performance will be achieved.

Key assumptions

mmboe Million barrels of oil equivalent mmboed Million barrels of oil equivalent per day mmbtu Million British thermal units mtpa Million tonnes per annum OGP Oil and Gas Producers Association Opex Operating expenditure Ph Phase PE Production efficiency QCLNG Queensland Curtis LNG QGC QGC Pty Limited RRR Reserves Replacement Ratio (SEC data) SEC US Securities and Exchange Commission SPA Sale and Purchase Agreement sq km Square kilometres T&D Transmission & Distribution T1 Train 1 T2 Train 2 tcf Trillion cubic feet TRCF Total Recordable Case Frequency UK United Kingdom US or USA United States of America WDDM West Delta Deep Marine YOY Year on Year

Definitions

∆ Increase or (decrease) $ United States dollar $A Australian dollar > Greater than ~ Approximately AUD Australian dollar bbl Barrel of oil bn One thousand million boe Barrels of oil equivalent BRL Brazilian Real ca Circa Capex Capital expenditure CNOOC China National Offshore Oil Corporation DD&A Depletion, Depreciation & Amortization E&A Exploration and Appraisal E&P Exploration and Production EWT Extended Well Test FCS Field Compressor Station FPSO Floating Production Storage and Offloading HH Henry Hub HOA Heads of Agreement HPHT High Pressure High Temperature kboed Thousand barrels of oil equivalent per day LNG Liquefied Natural Gas

43