AWE Limited Bruce Clement, Managing Director

Macquarie Conference, 2 May 2013

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Disclaimer

This presentation may contain forward looking statements that are subject to risk factors

associated with the oil and gas businesses. It is believed that the expectations reflected

in these statements are reasonable but they may be affected by a variety of variables

and changes in underlying assumptions which could cause actual results or trends to

differ materially, including but not limited to: price fluctuations, actual demand, currency

fluctuations, drilling and production results, reserve estimates, loss of market, industry

competition, environmental risks, physical risks, legislative, fiscal and regulatory

developments, economic and financial market conditions in various countries and

regions, political risks, project delay or advancement, approvals and cost estimates.

This presentation may also contain non-IFRS measures that are unaudited but are

derived from and reconciled to the audited accounts. All references to dollars, cents or $

in this presentation are to Australian currency, unless otherwise stated.

The reserve and resource information contained in this report is based on information

compiled by David Gaudoin (Vice President, Exploration & Development, Indonesia) and

Ian Palmer (General Manager, Development). Mr Gaudoin is a petroleum geologist,

holds a Masters Degree in Petroleum Geology, and has 23 years’ experience in

petroleum exploration. Mr Palmer holds a Bachelor Degree in Engineering and has 32

years’ experience in the practice of petroleum engineering. Both have consented in

writing to the inclusion of this information in the format and context in which it appears.

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AWE Limited – overview

Australian energy company focused on upstream oil and gas and related energy opportunities

Portfolio of production, exploration and development assets across Australia, NZ, USA and Indonesia

Listed on ASX (ASX: AWE), market capitalisation more than $650 million

Strong Board and Management

120 employees with offices in Sydney, Perth, New Plymouth (NZ) and Jakarta

522.1 million ordinary shares on issue

Based in Australia, focused on developing growth assets in key markets 3

Guidance for FY 2012-13 2012-13

Guidance

YTD at 31

March 2013

Production (million BOE) 4.9 to 5.3 3.7

Revenue ($m) 270 to 300 222

Development expenditure ($m) 150 to 180 120

Exploration expenditure ($m) 50 22

105

103

90

95

100

105

110

115

120

AWE ASX Energy Index

AWE performance vs ASX Energy Index (Index 100 at 1-Jan-13)

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Strategic, regional focus

Conventional and unconventional O&G assets in Australia, NZ, USA and Indonesia 4

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3Q Update (as at 31 March 2013)

On target to achieve 2012-13 operational goals

Production steady at 1.3 million BOE, YTD 3.7 million BOE

Sales revenue of $77 million, YTD $222 million

Field EBITDAX up to $49 million, YTD $141 million

Development expenditure $20 million, YTD $120 million

Exploration expenditure $6 million, YTD $22 million

Net debt reduced to $29 million, undrawn facilities totalled $212 million

Sugarloaf 2P Reserves up 67%, an increase of 6.4 million BOE

Improving safety performance & no reportable environmental incidents

On track to achieve full year production within guidance range of 4.9 – 5.3 MMBOE 5

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3Q production summary

YTD production comprised of 58% gas and 42% liquids 6

REGION AND ASSET INTEREST 3Q PRODUCTION YEAR TO DATE

PRODUCTION

3 months to March 2013 9 months to March 2013

Australia

BassGas 46.25% 379 769

Casino/Henry 25% 348 1,115

Cliff Head 57.5% 136 442

Perth Basin* 33-100% 110 335

New Zealand

Tui* 42.5% 148 536

USA

Sugarloaf 10%, net 7.5% 211 480

TOTAL (‘000 BOE) 1,333 3,677

*Denotes Operatorship (not all Perth Basin assets operated) For

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YTD performance summary

Strong production base delivers solid revenue and cash flows 7

0

500

1000

1500

2000

2500

3000

3500

4000

0

50

100

150

200

250

YTD Q1 YTD Q2 YTD Q3

'000 B

OE

A$ m

illio

n

YTD Cumulative Performance Summary

Sales (A$ million) EBITDAX (A$ million) Production ('000 BOE)

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3Q Update (as at 31 March 2013)

On target with delivery of major growth projects

Sugarloaf – wells to be drilled in 2013 increased to 37 with at least 2 in the Austin Chalk; test results for tighter well spacing due mid-year

Ande Ande Lumut (AAL) – major milestone achieved: regulator approval for tendering plan; entering FEED contracting stage for WHP and FPSO; preparing to farm out up to 50% of project with data room to open in June; FID on schedule and expected before end of 2013

WA Unconventional Gas – Senecio tight gas development feasibility study nearing completion; promising test results from Kockatea and Carynginia Shales at Arrowsmith-2

Focused Exploration Program – currently drilling Lengo-2 well in Indonesia; planning to drill Oi-1 exploration well in NZ before end 2013; pursuing additional conventional and unconventional opportunities in Perth Basin, South East Australia and Indonesia

AWE is well positioned to deliver growth from its development & exploration pipeline 8

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Building a growth platform

Production outlook reflects significant liquids growth & exposure to domestic gas prices

1

2

3

4

5

6

7

8

9

10

11

12

2012 2013 2014 2015 2016 2017 2018 2019 2020

millio

n B

OE

Production outlook: 2P Reserves plus 2C AAL (50%), Sugarloaf, Pateke, Lengo, Trefoil & Senecio

2C Trefoil, Lengo &Senecio

2C AAL, Sugarloaf& Pateke

Guidance Range

2P Reserves

Note: As at 31 December

2012, based on Brent oil

price of US$100 per bbl,

illustrative model only and

not formal company

guidance

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Creating shareholder value

Focused on delivering strategic initiatives to grow shareholder returns 10

• Identify, pursue and

develop quality assets

• Leverage core skills into new opportunities

• Focus on delivering

opportunities near existing infrastructure

• Optimise production and performance from core assets

Deliver Full Potential in

Base Business

Maximise Near Field

Opportunities

Grow through exploration

and acquisitions

Develop Opportunities in New Energy

Shareholder value creation will

be achieved by focusing on:

Achieving growth through

delivery of current portfolio

− Grow cash flows and

reserves through

existing assets and

opportunities

Achieving growth beyond

delivery of current portfolio

− Focus on where we

have advantage and

where new

opportunities are

available

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Growth built into asset portfolio

Development projects continue to enhance Reserves – Sugarloaf 2P Reserves up 6.4 MMBOE

0

20

40

60

80

100

120

140

160

180

200

millio

n

BO

E

Anambas and Lengo, Indonesia

Australian Gas

Australia & NZ Liquids

Ande Ande Lumut, Indonesia

AWE 2P Reserves and 2C Resources (as at 31 December 2012)

2P 2P+2C

Sugarloaf

Note: Includes 100% AAL but does not include Perth Basin shale

gas. Includes Sugarloaf 2P Reserves and 2C Resources upgrade

2P Reserves - Gas 2P Reserves - Gas

2P Reserves - Liquids 2P Reserves - Liquids

Development projects will drive 2P growth

Note: 2P Reserves at 31 December 2012 and including Sugarloaf

2P Reserves upgrade

11

Trefoil, White Ibis, Rockhopper, Netherby,

Blackwatch, Elegans, Senecio & Snottygobble

Trefoil, White Ibis, Rockhopper, Cliff Head 9,

Pateke & Amokura Infill

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Major development projects

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Ande Ande Lumut (100%, Operator)

AAL oil project is located in the North West

Natuna PSC, Indonesia

76 million barrels of recoverable oil (gross,

2C estimate)

AWE has significantly improved the project

development plan including subsurface work

and facilities design

Further upside potential from deeper G

Sand reservoir, exploration within PSC and

other opportunities adjacent to the PSC

Independent audit and certification of

Contingent Resources being done by RPS

Farm-out on track - data room opens in June

and FID scheduled for end of 2013

Data room opens in June, strong interest from potential investors 13

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Ande Ande Lumut (100%, Operator)

Approved POD comprises $600 million gross

capex plus leased FPSO (AWE’s capex

commitment will reduce after farm-out)

FPSO bridge linked to WHP, up to 40

horizontal wells, ESPs utilised

Capex spread over 4 years from 2014,

minimal costs pre FID (<$20 million)

Drilling comprises >60% of total capex, but

project will generate revenue and begin to self

fund soon after first oil

Achieved major milestone with regulator

approval of FPSO tender plan - now entering

FEED contracting stages for WHP and FPSO

Project can be funded from balance sheet & future operating cash flows 14

AAL Development Concept

Source: Genting POD

AAL Development Concept

Source: AWE Limited

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Sugarloaf AMI (10%, net 7.5% after royalties)

Independent review of reserves by D&M

complete - 2P Reserves increased by 6.4

MMBOE, or 67%, to 15.9 MMBOE

Production up 282% YTD v prior year

81 wells (gross) online at end of March

2013 with further 5 in progress

Typical well costs of US$8-9 million

Expected 37 new wells (gross) to be

drilled in calendar 2013

Upside potential being actively

pursued:

• Tighter well spacing

• Austin Chalk and deeper

shale plays

Recent Sugarloaf deals (non-AWE) demonstrate significant increase in value

Sugarloaf AMI

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BassGas (46.25%)

Yolla-3 workover successful and production

resumed in April; Yolla-4 wireline underway

Aim to restore full production and access

additional reservoir zones

Working with Operator to de-risk engineering and

planning for MLE development drilling and

compression installation

Development drilling provides well

redundancy and sustained

production capacity

Compression will maximise long

term reservoir performance

JV decision on sequencing and timing

of remaining MLE work expected

soon, with FID mid 2013

Long-term production asset with near-field opportunities

Jack-up drill rig alongside Yolla platform, August 2004

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Compression module, October 2012

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Building a growth platform

Pateke, Senecio and Sugarloaf offer near-term enhancement to production

1

2

3

4

5

6

7

8

9

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11

12

2012 2013 2014 2015 2016 2017 2018 2019 2020

millio

n B

OE

Production outlook: 2P Reserves plus 2C AAL (50%), Sugarloaf, Pateke, Lengo, Trefoil & Senecio

2C Trefoil, Lengo &Senecio

2C AAL, Sugarloaf& Pateke

Guidance Range

2P Reserves

Note: As at 31 December

2012, based on Brent oil

price of US$100 per bbl,

illustrative model only and

not formal company

guidance

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Funding a growth platform

AAL sell-down proceeds likely to be realised in FY 2013-14 18

-300

-200

-100

0

100

200

300

400

FY13 FY14 FY15 FY16 FY17 FY18

A$M

Forecast Annual Operating Cash Flow, Capex and Exploration 2P plus 2C AAL (50%), Sugarloaf and Pateke

Cash Inflows

Sale of 50% AAL, atbook value

Operating Cashflow

Cash Outflows

Exploration

Capex

Annual Net CashFlow from Assets

1

1 Sales revenue less

production cost, tax and

royalties but before

exploration expense.

Based on Brent oil price

of US$100 per barrel.

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Production and geographic shift

AAL project rebalances geographic spread and substantially increases oil production 19

NOTES: 1. Based on 2P Reserves Production Forecast + AAL (50%), Sugarloaf and Pateke

2. Based on Brent oil price of US$100 per bbl

3. Illustrative comparison only and not formal company guidance

AAL acquisition has materially altered the geographic spread of AWE’s future reserves and

resources

Asia is a key growth market and presents opportunity for AWE to leverage its key strengths

to drive growth in this region

4%

20%

76%

FY 2011-12 actual production

Australia New Zealand USA

34%

14% 5%

47%

FY 2016-17 production outlook

Australia New Zealand USA Indonesia

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Exploration & Appraisal

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Exploration activity increasing

Focused and disciplined approach to exploration and appraisal 21

REGION AND ASSET INTEREST EXPLORATION/APPRAISAL

ACTIVITY

Australia

Perth Basin* 33-100% • Senecio tight gas development feasibility study

substantially complete

• Promising results from shale gas and tight gas testing

program at Arrowsmith-2

• Evaluation of other opportunities using new 3D seismic

New Zealand

Tui* 42.5%** • Plan to drill Oi-1 exploration well in late 2013

Indonesia

Anambas* 100% • Planning farm out and further exploration and appraisal

drilling

Lengo 42.5% • Currently drilling Lengo-2 well

Indonesia Shale* TBA • Initial shale study complete

North West Natuna* 100% • Evaluating exploration potential of near field

opportunities

*Denotes Operatorship (not all Perth Basin assets operated) ** AWE currently has 25% equity in the Oi-1 well with the right to buy back to 42.5% equity

Exploration budget approximately $50 million per year

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Perth Basin - Senecio-2 (50%, Operator)

50-100 Bcf tight gas opportunity

Development feasibility study substantially

complete – reviewing preliminary findings

Completion of study expected in 4Q, work on

environmental approvals has commenced

Close proximity to existing infrastructure

improves economics

Flow test over 5m interval in Sept 2012

achieved stabilised gas rate of 1.35 MMscf/d

and produced 4.65 MMscf gas and ~65 bbls

of oil/condensate

Evaluating other tight gas opportunities within

the Perth Basin

Senecio offers significant Reserves potential, possible 50-100 Bcf recoverable gas field 22

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Perth Basin - Arrowsmith-2 (44.25%)

Potential farm out of shale assets once testing and evaluation complete

5 shale gas and tight gas zones fracture stimulated,

hydrocarbons recovered from all zones, plugs set

between zones

High Cliff Sandstone achieved maximum gas flow rate of

0.78 MMscf/d

Kockatea shale flowed back oil and gas

Carynginia produced initial maximum

gas flow rate of 0.35 MMscf/d

Well to be recompleted using smaller

tubing string - testing of Carynginia and

remaining zones through 2013

Evaluating potential acquisition of 3D

seismic in 2013

600,000 net acres held by AWE in Basin

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Indonesia and New Zealand

Lengo-2 appraisal well drilling underway in

the Bulu PSC (42.5%), offshore Indonesia

Reviewing field development options for

Anambas gas discovery (100%, Operator),

including possible farm-out to undertake

further exploration and appraisal drilling

Evaluating exploration potential of near

field opportunities in North West Natuna

PSC (100%, Operator)

Indonesian shale gas study completed –

awaiting regulator to progress next stage

Drilling program in New Zealand to start

late 2013 in Tui permit area, including the

Oi-1 exploration well (25%, Operator)

Adding value to 2C Resources to drive next growth phase

Kan Tan IV drilling rig

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Activity summary 2013 calendar year

Increasing activity levels will generate growth

Region Asset Activity Description Q1 Q2 Q3 Q4

Australia BassGas O Yolla-3 workover & Yolla-4 wireline

D MLE sequencing decision*

Casino/Henry E/A 3D Reprocessing

Cliff Head O Evaluation of CH9 injection conversion

Senecio-2 A Development feasibility study

Arrowsmith-2 E/A Shale gas and tight gas testing

New Zealand Tui/Pateke D Development drilling Pateke 4H

Oi E Exploration drilling Oi-1

USA Sugarloaf D Drill 37 wells in calendar 2013

A Evaluate tighter spacing, Austin Chalk

Indonesia AAL D Farm-out & FID

Lengo A Appraisal drilling Lengo-2

Anambas A Evaluation pre farm-out

Shale Study E/A Negotiations with regulator on next stage

Farm-out FID

O – Operations D – Development A – Appraisal E – Exploration * Compression installation/development drilling

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AWE delivering on growth initiatives

Well funded with strong operating cash flows

Development pipeline funded through operating cash flows and modest debt facility

Growth drivers already built into exciting portfolio of 2C Resources

Good balance of liquids and gas; leveraged to rising Australian gas prices

Conventional and unconventional asset plays

Expansion into Indonesia accelerating

Progressing AAL development project in Indonesia; sell-down up to 50% and FID in 2013

Unconventional oil and gas plays building momentum

Sugarloaf (Eagle Ford) outperforming; 2P Reserves increased 67% (+6.4MMBOE)

Promising test results from Perth Basin shale gas; tight gas feasibility study nearing completion

Early stage involvement in Indonesian shale

Focused and disciplined exploration and appraisal activity

Oi, Lengo and Anambas setting scene for next exploration drilling phase

AWE has positioned itself for a sustained period of growth 26

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Thank You Questions

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Appendix Half Year Financials and supplementary information

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Production performance

All production assets online, potential to further optimise asset performance

6.1 6.1

4.7

4.9-5.3

3.3 3.1

2.9

2.3

0

1

2

3

4

5

6

7

millio

n B

OE

Production for the period ending 31 December 2012

Gas

LPG

Condensate

Oil

Guidance Range

Full Year Production

FY10 FY13 FY12 FY11

H1 FY H1 FY H1 FY H1 FY (f)

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Sales Revenue

Average price for Brent oil over the half year was A$106

354

305 298

270-300

187

135

158 145

0

50

100

150

200

250

300

350

400

A$M

Sales Revenue for the period ending 31 December 2012

Gas

LPG

Condensate

Oil

Guidance Range

Full Year Revenue

FY10 FY13 FY12 FY11

H1 FY H1 FY H1 FY H1 FY (f)

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Earnings Analysis

Earnings impacted by lower production in the first half

145

35

13

54

45

5

6 4

18

0

20

40

60

80

100

120

140

160

Revenue Field Opex Amortisation Exploration &EvaluationExpenses

Other EBIT Net Interest Taxation NPAT

A$M

Net Profit after Tax for period ending 31 December 2012

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Field EBITDAX

BassGas shut-in impacted performance in South East Australia

37 35

28

4

34

17

26

14

0

5

10

15

20

25

30

35

40

New Zealand South-Eastern Australia Western Australia United States

A$M

Half Year Field EBITDAX for the period ending 31 December 2012

H1 2012 H1 2013

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Cash Flow Analysis

BassGas and Sugarloaf accounted for majority of development expenditure

43 40

44

77

102

22 1

0

20

40

60

80

100

120

140

160

180

Opening balance asat 30 Jun 2012

Operating cashflow*

Borrowings Development Exploration Other Closing balance asat 31 Dec 2012

A$M

Cash Flow for period ending 31 December 2012

*Cash flow from operating activities excludes exploration expense.

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Investment Expenditure

Development and exploration activity within guidance

55 57

172

60

32

8

142

67

39

16

200-230

0

50

100

150

200

250

FY10 FY11 FY12 FY13

A$M

Annual Capex plus Exploration Expenditure

Capital Expenditure Exploration FY Guidance Combined

BassGas

Sugarloaf

Other

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Half Year earnings breakdown

HY to

Dec 2012

$ million

HY to

Dec 2011

$ million

Revenue 146.0 158.6

Operating costs (53.8) (54.4)

Amortisation (45.4) (48.3)

Exploration costs expensed (4.9) (9.7)

Asset impairments/reversals - (4.2)

Net other (11.0) 7.9

Profit before tax 30.9 49.9

Tax (expense)/benefit (17.7) (20.2)

Statutory net profit 13.2 29.7

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Segmental reporting

$ millions Total New

Zealand

South-

Eastern

Australia

Western

Australia

United

States

Exploration

Activities

Sales revenue 145.1 44.9 35.3 42.0 22.9 -

Production costs and

royalties (53.8) (11.3) (18.1) (15.6) (8.8) -

Net field contribution 91.3 33.6 17.2 26.4 14.1 -

Amortisation (45.3) (9.1) (16.1) (9.6) (10.5) -

Exploration expenses (4.9) - - - - (4.9)

Segment Profit 41.1 24.5 1.1 16.8 3.6 (4.9)

Unallocated

income/(expenses) (10.2)

Net profit before tax 30.9

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Cash flow analysis

HY to

Dec 2012

$ million

HY to

Dec 2011

$ million

Opening Cash 42.8 117.2

Net cash flow from operations * 39.4 75.4

Asset disposals - -

Development spending (102.2) (43.7)

Exploration spending initially capitalised (17.1) (1.2)

Proceeds from borrowings 77.3 -

Other (0.6) 18.8

Closing Cash 39.6 166.5

* Includes exploration & evaluation costs (5.0) (7.6)

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Balance Sheet and Funding

Cash of $39.6 million at half year

Drawn debt of $93.8 million at half year

Net debt of $54.2 million, undrawn facilities of $206 million at half year

Conservative gearing ensures funding capacity for future activities

Balance Sheet Item 31 Dec 12 $million

Total Assets 1,134

Exploration and evaluation assets 95

Oil and gas assets 899

Total Liabilities 267

Interest bearing liabilities 91

Net Assets 867

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Energy price projections

Industry forecasts sustained high oil prices and strong domestic gas demand

Note: Annual average price for Brent crude oil on the Intercontinental exchange.

$0

$50

$100

$150

$200

$250

$300

2010 2015 2020 2025 2030 2035 2040

Oil

Pri

ce (

US

do

llars

pe

r b

arr

el)

Brent Oil Spot Price Projections (US EIA – Annual Energy Outlook 2013)

Brent Spot Price (nominal $/barrel)

Brent Spot Price (real 2011 $/barrel)

$0

$5

$10

$15

$20

2010-11 2015-16 2020-21 2025-26 2030-31

Gas P

rice (

Au

str

ali

an

do

llars

pe

r G

J)

Melbourne Wholesale Fuel Cost (Gas) Projections (ACIL Tasman)

Levelised price projections (nominal $/GJ)

Levelised price projections (real 2012-13 $/GJ)

The US Energy Administration continues to forecast strong oil price growth

(in real terms) over the next 30 years, even with substantially reduced

projected US imports

Whilst East Australian gas prices remain low compared to our Asian export

markets, most industry experts expect the domestic gas price to rise sharply

over the next 5-10 years as local supply increases to meet LNG exports

Note: AEMO NTNDP modelling Final June 2012 Melbourne Gas Price - Planning Scenario Sensitivity 4

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Domestic contracted sales gas

Substantial uncontracted domestic gas position with exposure to gas price growth

48% of AWE’s Australian

2P gas reserves and 76%

of 2P+2C gas resources

remain uncontracted

30 million BOE 2P

Australian gas reserves

Additional 34 million BOE

Australian 2C gas

resources

AWE is well placed to take

advantage of future gas

price opportunities

0

10

20

30

40

50

60

70

2013 2014 2015 2016 2017 2018 2019 2020

TJ/d

ay

Financial Year (June 30)

AWE Net Australian Sales Gas Production Forecast (average TJ per day)

2P Reserves - Contracted 2P Reserves - Uncontracted

2C Resource - Uncontracted 2C Resource Potential

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Strong Board and Management

Experienced team focused on maximising value and delivering growth

Non-executive Directors

Bruce Phillips • Chairman

• 30+ years’ of oil & gas technical, financial and

managerial experience

Andy Hogendijk • 30+ years’ of senior financial management

experience

• Chairman of the Audit and Governance

Committee

Dave McEvoy • 40+ years’ experience in international O&G

exploration and development

• Chairman of the Sustainability Committee

Ken Williams • 20+ years’ operational experience in

corporate finance, treasury and financial risk

management

• Chairman of the People Committee

Vijoleta Braach-

Maksvytis

• 20+ years’ experience in organisational

change, formation of cross-sectoral and global

partnerships, the commercialisation of

technology, and intellectual property strategy

Ray Betros • 30+ years’ experience specialising in

international business and project

development and technical management

Senior Management

Bruce Clement • Managing Director

• Engineer with 30+ years’ experience in oil & gas

in Australia and internationally

Ayten Saridas • Chief Financial Officer

• 20+ years’ experience in corporate finance,

treasury and financial risk management in

resources and financial markets

Dennis Washer • Chief Operating Officer and GM New Zealand

• 30+ years’ management experience in

international O&G industry

Dave Gaudoin • VP, Exploration & Development, Indonesia

• 20+ years’ of management & geoscience

experience with major international O&G

corporations

Neville Kelly • Company Secretary

• 30+ years’ of financial, commercial and company

secretarial experience in the upstream oil and

gas industry

Ian Palmer • General Manager Development

• 30+ years’ engineering, operational and project

management experience in upstream O&G

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AWE 2P Reserves as at 31 December 2012

Sustainable operating cash flow from existing 2P Reserves

2P Reserves

Project/Area Equity (million boe)

BassGas 46.25% 27.9

Otway Basin 25.0% 8.5

Cliff Head 57.5% 2.9

Onshore PB 33-100% 2.1

Tui 42.5% 2.8

Sugarloaf 7.5%* 15.9

Total 60.1

*Net Revenue Interest, post Royalty (Working Interest 10%), includes upgraded

2P Reserves

42

27.9

8.5

2.9

2.1

2.8

15.9

BassGas

Otway Basin

Cliff Head

Onshore PB

Tui

Sugarloaf

For

per

sona

l use

onl

y

AWE 2C Resources as at 31 December 2012

2C Resources increased following AAL acquisition

2C Resources

Project/Area Equity (million boe)

Bass Basin 44.75-46.25% 37.3

Otway Basin 25.0% 4.8

Cliff Head 57.5% 1.2

Onshore PB 50%-100% 8.2

Tui 42.5% 1.5

Sugarloaf 7.5%* 5.1

Ande Ande

Lumut 100% 43.0

Other Indonesia 42.5-100% 30.9

Total 132.0 *Net Revenue Interest, post Royalty (Working Interest 10%), includes upgraded

2C Resources

43

37.3

4.8

1.2 8.2

1.5 5.1 43

30.9

Bass Basin

Otway Basin

Cliff Head

Onshore PB

Tui

Sugarloaf

Ande Ande Lumut

Other Indonesia

For

per

sona

l use

onl

y