The document is a presentation of BG Group's 2012 results. It provides highlights such as a 4% increase in total operating profit to $8.047 billion, with upstream profit of $5.464 billion. It discusses financial results, strategic priorities for 2013 including production delivery and major project milestones. Key capital expenditure projects are outlined along with a $10.4 billion cash capex budget and $8.1 billion in portfolio rationalization by end of 2013. Safety and operational performance are reviewed along with 2013 production outlook of 630-660 kboed.

1. 2012 results
presentation
5 February, 2013
Deepsea Metro I drillship
Tanzania 1

2. Welcome
Andrew Gould
Chairman
LNG storage tank
2
Curtis Island, Australia

3. 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

4. Introduction
Chris Finlayson
Chief Executive
FPSO 2 Cidade de São Paulo departure
Brazil

5. 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

6. 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. Full year results
Den Jones
Interim Chief Financial Officer
Main pipeline network
7
Narrows crossing, Queensland, Australia

8. Reporting segment changes
Old segment split
E&P LNG T&D
Shipping &
E&P Liquefaction T&D
Marketing
New segment split
Upstream LNG Shipping T&D discontinued
& Marketing
8

9. Financial highlights: Q4 2012
Q4 Q4
Δ YOY
2012 2011
Total operating profit $1 831m $2 089m -12%
Upstream $1 169m $1 334m -12%
LNG Shipping & Marketing $658m $784m -16%
Cash generated by operations $2 248m $2 655m -15%
Earnings $1 030m $1 456m -29%
Underlying earnings* $1 030m $1 179m -13%
* Q4 2011 restated to exclude $277m one-off tax credit
Upstream segment includes E&P and liquefaction activities 9

10. Financial highlights: 2012
2012 2011 Δ YOY
Total operating profit $8 047m $7 732m +4%
Upstream $5 464m $5 440m -
LNG Shipping & Marketing $2 577m $2 282m +13%
Cash generated by operations $10 715m $9 773m +10%
Earnings $4 395m $4 251m +3%
Dividend per share 26.14 cents 23.76 cents +10%
Upstream segment includes E&P and liquefaction activities 10

11. Upstream operating profit
Year on year Upstream operating profit change ($m)
8000
534 352
334
6000 158
5440 18 5464
291 Liquefaction 346 Liquefaction
4000
5149 E&P 5118 E&P
2000
0
2011 Volume Price Opex DD&A Other 2012
11

12. E&P unit cost performance
Annual unit opex cost ($/boe) Annual unit DD&A cost ($/boe)
BG Group 2012 BG Group 2012
BG Group 2011 BG Group 2011
Peer 2011 Peer 2011
0 20 40 0 10 20
Source (2009-2011): Evaluate Energy 2012
BG Group Peer Group includes Super Majors and US and European Integrated Majors
12
12

13. Strong reserves replacement
BG Group’s reserves replacement 3 year total reserves replacement
250%
217%
200%
176%
150% BG Group 2010-2012
BG Group 2009-2011
Peer 2009-2011
100%
Peer group includes Super
Majors and US and European
Integrated Majors
50%
0%
1 year SEC 3 year SEC
proved RRR proved RRR 0% 100% 200% 300%
Source: Evaluate Energy 2012 13
13

14. LNG* operating profit
Year on year LNG Shipping & Marketing operating profit change ($m)
3000 2923
512 217
2577 Liquefaction
2282
2000
1000
0
2011 Margin & Mix Shipping 2012 Old LNG segment
* LNG Shipping & Marketing 14

15. LNG sources and destinations
Sources loaded (mtpa) Destinations delivered (mtpa)
15 Long-term 15 Sales volume
Short-term contracts
13.4 13.4 (12.1 mtpa)
third-party (11.6 mtpa)
purchases 12.7 0.6 Ship use 12.7
1.5 0.6
1.0 1.5 Europe 0.5
South 2.6
10 10 2.7
Long-term America
6.2 third-party 6.1
purchases
5 5 6.8 Asia 7.7
5.7 Operated
5.6
production
1.8 USA 1.3
0 0
2011 2012 2011 2012
15

16. 2013 LNG outlook
• 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 16

17. 2012: sources and uses of funds
($bn) • Net cash inflow of $0.9 bn
16 15.4 – Net additional borrowings of $1.2 bn
1.2 Borrowings 14.5
– Net cash outflow $0.3 bn before borrowings
0.6 1.4 Dividends
Other
& interest
• Capital investment: $10.4 bn (cash basis)
12 2.9 Disposals
2.7 Tax
• 94% cash disbursements self-funded
– Strong operating cash flow
8 – $2.9 bn through sale of non-core businesses
10.7 Operating 10.4
cash flow Capex
4
0
Sources Uses
17

18. 2012-13: cash capex split
($bn)
15
12.0
11.5 0.8
0.8
0.3
10.4
10 1.1 Other 3.0
Base
2.7
assets
2.7
1.6 Brazil
5
5.0 5.5
Australia*
0
2012 Q1 guidance Australia Other 2012 2013
* 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 18

19. Portfolio rationalisation progress
Total capital release ($bn) • Portfolio refocused to E&P and LNG
10 • Capital release of $8.1 bn by end 2013
• Significantly exceed $5 bn target
• Key milestones in Q4
End 2013 – QCLNG sell-down: HOA signed
4.3
target
– Comgás disposal: completed
5
8.1 – Gujarat Gas disposal: SPA signed
– Quintero LNG disposal: part completed
3.8 – Bolivia-Brazil pipeline disposal: SPA signed
– BG Italia Power disposal: completed
0 – MetroGAS disposal: SPA signed
2012 2013
Completed Agreed*
* Includes $0.5bn of cash capex saving in 2013 19

20. Financial structure & liquidity
Cash ($m) and gearing (%) • Maintain a robust financial structure
5000 30%
• Gearing fell from 27% to 24% (2011-12)
– Cash balance increased to $4.4 bn
4000 • Diversifying & extending funding sources
20% – Average gross debt maturity up to 17 years
3000 – Cash & undrawn committed bank facilities:
$9.6 bn
2000
10%
1000
0 0%
2010 2011 2012
Cash balance Gearing
20

21. Excellence in execution
Armada
UK

22. 2012 safety performance
TRCF* (per million work hours) • Two fatalities in 2012
2.5 – Lessons learned shared around Group
Group • Majority of Group** met TRCF target
2.0 – Top quartile performance***
Industry
Average*** • QGC missed target
1.5
2012 Group target
– Improving contractor management
Top • Focus on process safety & asset integrity
Quartile***
1.0 Group
excluding
QGC
0.5
0.0
2008 2010 2012
*Total recordable case frequency (includes employees & ** Excludes QGC
contractors working on operated assets) *** OGP industry benchmark 2011 22

23. Base asset production performance
Variance to 2012 budget (kboed) • 2012 base asset production
10
– Majority producing close to expectations
• 2008-12 (excluding UK and Egypt)
0
– 550 mmboe produced
– 89% production efficiency
-10 – No production decline (post-investment)
• UK and Egypt
-20 – Major driver of production shortfall
-30
Kazakhstan
Tunisia
Trinidad
India
Norway
Thailand
Bolivia
UK
Egypt
23

24. Egypt: WDDM production performance
Production (kboed) & PE* (%) • Two producing assets (Rosetta & WDDM)
160 100%
• Rosetta producing to plan
• WDDM
– Good production efficiency of >90%
120 75%
– Recent decline due to water breakthrough
• 2012 WDDM development phase
80 50%
– 9 new wells & compression
– Added production
40 25%
– Wells performed close to expectations
– Higher water production & lower gas
0 0% volumes
2008 2010 2012
WDDM Budget WDDM PE%
* Production efficiency 24

25. Egypt: WDDM recovery plan
• 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

26. UK: production performance
Production (kboed) & PE (%) • Significant value 2008-2012
200 100% – ca $12 bn operating profit
– Added ~200 mmboe of reserves & resources
150 75% • Non-operated assets; 2/3 of 2012 shortfall
– Elgin/Franklin well integrity: 45% of shortfall
– Buzzard shut-down extended
100 50%
• Operated assets
– Limited accommodation
50 25%
– Safety critical maintenance carried out
– Unable to complete all maintenance
0 0% improvements to fully recover PE in 2012
2008 2010 2012
UK other Elgin hub Budget
UK other PE% Elgin hub PE%*
* Elgin/Franklin PE @ full year 2012 26

27. 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
Buzzard platform
UK
27

28. 2013 production outlook
Quarterly milestones • 7 projects coming onstream
Q1
• Elgin/Franklin restart
Brazil FPSO 2 onstream ✓ • Growth projects offset by
Everest East expansion onstream
– Strategic decision to lower production in US
Elgin/Franklin production restart
– Natural decline in Egypt
Q2
Brazil FPSO 3 onstream – Maintenance shutdown in Karachaganak
Karachaganak planned shutdown – Reduced equity in QCLNG
Q3 • 2013 production outlook: 630-660 kboed
Bongkot N Ph 3K onstream
Itau Ph 2 onstream
UK shutdowns
Q4
Jasmine onstream
Margarita Ph 2 onstream
28

29. Excellence in execution
Kenya water treatment plant
Australia

30. Good progress on QCLNG
Current status
Upstream
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
Pipeline*
100% welded, 75% in the ground, crossing and
Gas collection header
tie-ins progressing
Export pipeline 74% welded, 45% in the ground
Narrows crossing 50% welded, dredging complete
LNG
24 on Curtis Island, further 25 in transit from
LNG modules
Thailand
* Progress percentages apply to mainline pipelines and exclude crossings / tie-ins 30

31. QCLNG on track for 2014 LNG sales
2013 2014
Q1 Q2 Q3 Q4 H1 H2
Wells: 1290 1450 1600 1750 >2000 wells
Upstream
First major water facility (Kenya)
Central processing plant (Ruby)
Six FCSs (for Ruby)
Gas collection header
Pipeline
Narrows crossing
Export pipeline
Modules delivered*: T1 & common facilities T2
LNG
Gas in plant - start commissioning
LNG sales
* 80 modules in total (62 for train 1 and common facilities) 31

32. QCLNG on budget
• 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)
Tank construction, QCLNG
Curtis Island, Australia
* Value of work done 32

33. Brazil: good progress
• 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
FPSO 2
Santos Basin, Brazil • 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 33

34. 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
FPSO Cidade de Angra dos Reis
Santos Basin, Brazil
34

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 35

36. Exploration
Deepsea Metro I drillship
Tanzania36

37. 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

38. Exploration in 2013
Global 2013 E&A operations • Key wells
– Exploration: Egypt (Notus), Brazil
(Sagittario), UK HPHT (Thunderer & Jade S)
USA UK
2-3 wells 3 wells – First Kenya well around year end
Algeria Thailand
– Appraisal: Australia plays & Tanzania
Egypt 9 wells
2 wells
– Iara: 2 appraisal wells; test well designs for
1-2 wells field development
Brazil Kenya
Bolivia
3 wells 1 well
• Major seismic programmes
1 well
– Uruguay, Kenya, Tanzania, Egypt
Tanzania
1 well
1-2 wells
Australia
30-40 wells
• Sign new licences (gross 44000 sq km)
2 wells
– Honduras, Bolivia, Norway & UK
Appraisal / near term production
New plays
Play extenders
38

39. Total reserves & resources
Total reserves & resources (mmboe)
20000
18511
17130
16180
4583
15000 14494 3784
13126 3707
3433
3562
6160 6739
10000 5757
4931
3722
5000 3939 3758
3823
3383 3530
2600 2893 3247 3431
2459
0
2008 2009 2010 2011 2012
SEC Proved Reserves Probable Reserves* Discovered Resources** Risked Exploration
Total reserves & resources as at year end
*Adopted SEC definition for Probable reserves in 2009; Discovered resources called Unbooked resources until 2009 39

40. 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. 2012 results
presentation
5 February, 2013
Deepsea Metro I drillship
Tanzania41

42. Key assumptions
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
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. 42

43. Definitions
∆ Increase or (decrease) mmboe Million barrels of oil equivalent
$ United States dollar mmboed Million barrels of oil equivalent per day
$A Australian dollar mmbtu Million British thermal units
> Greater than mtpa Million tonnes per annum
~ Approximately OGP Oil and Gas Producers Association
AUD Australian dollar Opex Operating expenditure
bbl Barrel of oil Ph Phase
bn One thousand million PE Production efficiency
boe Barrels of oil equivalent QCLNG Queensland Curtis LNG
BRL Brazilian Real QGC QGC Pty Limited
ca Circa RRR Reserves Replacement Ratio (SEC data)
Capex Capital expenditure SEC US Securities and Exchange Commission
CNOOC China National Offshore Oil Corporation SPA Sale and Purchase Agreement
DD&A Depletion, Depreciation & Amortization sq km Square kilometres
E&A Exploration and Appraisal T&D Transmission & Distribution
E&P Exploration and Production T1 Train 1
EWT Extended Well Test T2 Train 2
FCS Field Compressor Station tcf Trillion cubic feet
FPSO Floating Production Storage and Offloading TRCF Total Recordable Case Frequency
HH Henry Hub UK United Kingdom
HOA Heads of Agreement US or USA United States of America
HPHT High Pressure High Temperature WDDM West Delta Deep Marine
kboed Thousand barrels of oil equivalent per day YOY Year on Year
LNG Liquefied Natural Gas
43