Origin Energy Limited ACN 000 051 696 • Level 45 Australia Square, 264-278 George Street, Sydney NSW 2000 GPO Box 5376, Sydney NSW 2001 • Telephone (02) 8345 5000 • Facsimile (02) 9252 1566 • www.originenergy.com.au

To Company Announcements Office Facsimile 1300 135 638

Company ASX Limited Date 20 May 2013

From Helen Hardy Pages 66

Subject APLNG CSG PRODUCTION – ORG REVIEW AND ASSET VISIT MAY 2013

Please find attached a release on the above subject. Regards

Helen Hardy Company Secretary 02 8345 5023 – helen.hardy@originenergy.com.au

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Origin Operational Review and Asset Visit

20-21 May 2013

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Important Notice

Each institution that reviews this presentation will be deemed to represent that it is a “qualified institutional buyer” within the

meaning of Rule 144A under the U.S. Securities Act of 1933. This presentation does not constitute investment advice, or an

inducement or recommendation to acquire or dispose of any securities in Origin, in any jurisdiction (including the USA). This

presentation is for information purposes only, is in a summary form, and does not purport to be complete. This presentation does

not take into account the investment objectives, financial situation or particular needs of any investor, potential investor or any

other person. No investment decision should be made in reliance on this presentation. Independent financial and taxation advice

should be sought before making any investment decision.

Forward looking statements

This presentation contains forward looking statements, including statements of current intention, statements of opinion and

predictions as to possible future events. Such statements are not statements of fact and there can be no certainty of outcome in

relation to the matters to which the statements relate. These forward looking statements involve known and unknown risks,

uncertainties, assumptions and other important factors that could cause the actual outcomes to be materially different from the

events or results expressed or implied by such statements. Those risks, uncertainties, assumptions and other important factors

are not all within the control of Origin and cannot be predicted by Origin and include changes in circumstances or events that

may cause objectives to change as well as risks, circumstances and events specific to the industry, countries and markets in

which Origin and its related bodies corporate, joint ventures and associated undertakings operate. They also include general

economic conditions, exchange rates, interest rates, the regulatory environment, competitive pressures, selling price, market

demand and conditions in the financial markets which may cause objectives to change or may cause outcomes not to be realised.

None of Origin Energy Limited or any of its respective subsidiaries, affiliates and associated companies (or any of their respective

officers, employees or agents) (the Relevant Persons) makes any representation, assurance or guarantee as to the accuracy or

likelihood of fulfilment of any forward looking statement or any outcomes expressed or implied in any forward looking

statements. The forward looking statements in this presentation reflect views held only at the date of this presentation.

Statements about past performance are not necessarily indicative of future performance.

Except as required by applicable law or the ASX Listing Rules, the Relevant Persons disclaim any obligation or undertaking to

publicly update any forward looking statements, whether as a result of new information or future events.

No offer of securities

This presentation does not constitute investment advice, or an inducement or recommendation to acquire or dispose of any

securities in Origin, in any jurisdiction.

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Australia Pacific LNG – CSG Production

Presented by Ross Evans

Group Manager, Exploration Appraisal & Development, QLD CSG

Origin Operational Review and Asset Visit

20-21 May 2013

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Origin is responsible for the upstream program for Australia

Pacific LNG, leveraging over 15 years of CSG production

experience …

4 |

APLNG tenure in the Surat and Bowen basins at 30 June 2012

… with Australia Pacific LNG having a dominant position in Queensland's premium CSG acreage

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0

4,000

8,000

12,000

16,000

20,000

24,000

28,000

Reserves ContingentResources

EstimatedProject

Requirements

PJe APLNG's Reserves & Resources

3P = 16,047

2P = 13,111

2C = 3,825

3C = 9,829

Ramp & tail Gas

T2 ~ 5,000

T1 ~ 5,000

APLNG‟s reserves base continues to expand, with 3P reserves of 16,047 PJ

and an additional 9,829 PJ of contingent resources …

5 |

… while 2P reserves are more than sufficient to cover gas requirements for all

domestic contracts, as well as off-takes from both trains.

• Large CSG reserves position

• Well developed resource base

• Low cost gas supports the Phase 1 development

• Prime acreage in both Qld CSG “sweet spots”

Domestic Gas

~ 2,000ORG Contract

~ 1,000

APLNG Reserves and Resources

(1) Represents ramp and tail gas for two trains, volume will vary depending on operation strategy

(2) APLNG operated wells designated to deliver first gas to both trains of the CSG to LNG project

Cumulative Production

Upst

ream

Pro

ducti

on C

ost

s

Continued efficiency gains

and technology improvements

will reduce costs over time

Phase 1 Phase 2

Lower unit

cost gas

production

Upstream Gas Production Costs

QGC GSA

~ 640

1

2

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APLNG permit

Conventional & CSG

Denison Trough fields

Permian CSG fields

Walloon CSG fields

Walloon Fairway

Permeability& net coalSweetspot

PermianpermeabilitySweetspot

Permian Fairways

Regional Geology

Regional Seismic Section

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7

Basement

Base mid Triassic

Base Jurassic

Key features• Major structural elements

• Major unconformities

• Coal measures sequences

Western Platform Moonie High

Bandanna/Tinowon/Baralaba

Reids Dome

Springbok

Present Day

Talinga

Hutton

Seis

mic

tra

vel

tim

e

Combabula Condabri

Undulla NoseTaroom TroughBalonne Nose

Walloon

Moolayember

Regional Geology

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Tipton

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8

Basement

Key features• Major structural elements

• Major unconformities

• Coal measures sequences

Base mid Triassic

Taroom Trough

Present Day

FairviewSpring Gully

ScotiaPeat

Moonie HighWestern Platform Balonne Nose

Bandanna/Tinowon/Baralaba

To the north …

Surface

Deeper erosionof section

Reids Dome

Undulla NoseSeis

mic

tra

vel

tim

e

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Spring Gully Coal Continuity

Spring Gully coal seams are continuous

over many 10‟s or possibly 100‟s of

kilometres

Walloons coal seams are thinner and the

packages which contain the seams vary in

thickness across the area

Walloon Coal Variability

Regional Geology - Depositional history creates key differences

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Thickening of Walloons section

Increasing net coal thickness

Walloon d

epth

Walloon n

et

coal th

ickness

High net coal

thickness

Scott et al., (2004) Scott et al., (2004)

West

Permeability

“Sweetspot”

Walloon Fairway

Undulla Nose

“Sweet spots” arise from the combination of greater coal

thickness and higher permeability

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East

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Australia Pacific LNG has a dominant position in Queensland‟s

premium CSG acreage

APLNG tenure in the Surat and Bowen basins at 30 June 2012

• APLNG is the only company that

has prime acreage in both of the

Queensland CSG “sweet spots”

• APLNG Phase 1 targets those

sweet spots for initial

development and ramp up to

first LNG

• APLNG has both diversity and

scale of resources to better

manage risks associated with CSG

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The Sweetspots demonstrate world-class reservoir properties

What makes a good CSG producer

1. High net effective coal thickness

2. Laterally extensive coals

3. High gas content saturation

4. High permeability

5. Shallow depth (low cost to drill)

6. Low CO2 content

Source: Journal of Petroleum Technology & APLNG data

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Condabri drilling has been progressing well …

• Over 250 Phase 1 wells drilled

to date

• Over 200 Condabri wells

drilled

• Over 100 Condabri wells

completed

• Net coal thickness results

exceed pre-drill expectations

… with results matching or

exceeding expectations0

5

10

15

20

25

30

Predicted Observed

Ne

t coal

thic

kn

ess

(m

)

209

256

83113

0

50

100

150

200

250

300

End 2012 End Q1 2013

Wells Drilled Wells Completed

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-

50.0

100.0

150.0

200.0

250.0

300.0

350.0

400.0

TJ/d

ay

Talinga Kenya Spring Gully Fairview Denison Trough Peat Moura

Production History

14 |

Origin/APLNG has the longest Queensland CSG experience, the largest

2P CSG reserves, highest CSG production and access to global expertise

Denison, Peat and Moura

Since 1990s

Spring Gully

Ph 1 & 2

Spring Gully

Ph 3 & 4

Spring Gully

Ph 5 & 6

Talinga

Ph 1

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Maximum well deliverability considerably higher than current

production levels indicate …

(1) Excludes domestic gas sales and pre LNG-start up gas sales to BG.

(2) Maximum average observable rate sustained over a week, looking back over one year, from wells that have been online for more than 6 months.

• The 1,100 operated wells to be drilled for Phase 1 are expected to produce 1,200

TJ/d1, with an additional 200 TJ/d1 from non-operated assets

• Current operated well production is over 1 TJ per well per day on average across

the Talinga and Spring Gully developments, however the observed maximum average

well deliverability2 across these areas is considerably higher

• Well production is turned down to meet market but operationally cycled to maintain

confidence in deliverability

Averages over Quarter

to 31 March 2013

Average well

production

Maximum average

well deliverability2

Talinga 1.6 TJ/day 2.5 TJ/d

Spring Gully 0.8 TJ/day 1.2 TJ/d

… whilst Phase 1 planning assumes 1.1 TJ/d per well on average

15% of Talinga wells

have maximum

deliverability over

4 TJ/d

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Well Production, Deliverability & Turn-down

• Typical phase 1 well forecast

to have:

– peak gas rate 1-2 TJ/d

– peak water rate 500-1000

bbl/d

– approx 50-70% of well‟s

reserves produced within

first 5 years

• Field deliverability to be

monitored during ramp

phase

• Excess deliverability to be

turned down to balance

supply & demand

Pro

ducti

on R

ate

Gas

Dewatering

Stage

Water

Stable Production

StageDecline Stage

Time

Time

Gas

Volu

me

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The CSG to LNG industry operates in a small proportion of the

overall Great Artesian Basin (GAB)

Location of CSG projects

Source: After Radke et al, 2000

The Surat Basin

is a sub basin of the

Great Artesian Basin

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Water produced by the industry (on average over 40 years) will be about

half the amount taken by other users (in perpetuity) and is small

compared to the annual recharge of the GAB

920,000

740,000

140,000

75,000

25,000

0 200,000 400,000 600,000 800,000 1,000,000

Average annual water production by the

CSG- LNG industry post 2015 – taken from

the coal measures

(Total surface water use in Surat Basin)

Typical annual water production by APLNG

post 2015 - taken from the coal measures

Current groundwater use in Surat Basin

- taken mainly from shallow aquifers

GAB and Surat Basin water figures

Estimated annual water levels (ML)

CSG water will be taken from the coal measures, while farmers and others take

water almost entirely from aquifers. The bulk of CSG water is re-injected or

directed to beneficial use so is not „lost‟

Annual recharge to the Great Artesian

Basin

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The coal seams are separated from the aquifers by layers of

hard rock - and the aquifers are monitored comprehensively

In APLNG‟s operating areas:

• We take water from the coal measures

• Others take it mainly from the shallow aquifers

• The coal measures are separated from the shallow

aquifers by ~100-250m of hard low-permeability rock

(equals a 30-80 story building)

• Our comprehensive monitoring system will identify

impacts on both the adjacent deep aquifers and the

shallow aquifers

• We have now completed our 2 year baselining

project to record measurements from 700 bores on

400 properties, to compare against in future

• We are obliged to make good in advance any

lowering of water levels in bores near our operations

• The Qld Water Commission has released its

Underground Water Impact Report that formally

identifies the bores that require a make-good

agreement

Our most noticeable impact will be on the small

number of farmers who have a bore direct into the

coal measures and who are close to our operations. We

are already in discussions to proactively make good

Aquifers - layers of

porous rock that

water can move

through slowly

System of

monitoring

bores both in

the aquifers

near the coals

and in the

aquifers nearer

the surface

Aquitards – hard

fine rock that

stops water

moving

Water bore –

typically 50-100

metres deep

Coal

measures

Avg

100-250

metres

of hard

rock

The information we are gathering will help make the Surat Basin one of the best

understood underground water systems in the world19 |

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Permeate Management Strategy - Locally Optimised Solution

Western Region:

Reedy Creek, Spring Gully

Eastern Region:

Talinga, Condabri

Primary: Aquifer Injection Primary: Landholder

Irrigation Scheme

Irrigation: existing

Pongamia

Contingent River Discharge

for Residual

Talinga

Existing

Pongamia

River

Discharge

Landowner

Irrigation

Strategy 2013+

Aquifer

Injection

A secure contingency facilitates

supply to landholders, while

ensuring no environmental harm

Environmentally

sustainable

Financially

feasible

Public

Interest

Distribution network between

Condabri and Talinga WTFs for

new and existing irrigation

Condabri

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In some areas where permeability of the coals is low, the process

of fraccing may be used to enhance the flow of fluids …

• Hydraulic Fracture stimulation or

„fraccing‟ is a method to increase

flow of gas and extract gas more

efficiently from the coal seam

• „Fracs‟ are placed using „frac‟ fluid

(primarily water) and sand at

pressure to create / connect /

open fractures in the coal

• The resulting fractures are ~5-20

millimetres thick

• Layers of rock, typically shales and

siltstones, act as barriers to confine

the „frac‟ from growing vertically

• Importantly, fracs are designed to

be contained within the coals as

intersecting other layers –

particularly aquifers – would

introduce unwanted additional

water into the coal seams inhibiting

gas productionFrom SPE 119351

… by creating small thin openings through the coals and rock 21 |

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Over 97% of the fraccing fluid used is water and sand with a

further 2% salt and minor concentrations of other common

household additives

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The CSG to LNG industry will produce broadly the same amount

of salt produced by other users

• All produced water will be treated with

Reverse Osmosis (RO)

• Currently more than 90% of the water

treated by RO becomes clean and usable -

expected to rise to 97.5% as the technology

develops which means less pond acreage

will be required

• The remainder is a highly concentrated

brine solution (salty water) that must be

dealt with

• Brine will be contained in fully lined ponds –

it can then be crystallised, completely

enclosed and disposed of in landfill

• Work is progressing on developing the

business case to take our successful salt

recovery pilot trial results to a full-scale

plant in collaboration with QGC. A shortlist

of sites for a full-scale salt recovery plant

has been announced

Destination of saltMajority

Indicative salt producedOver Project life

APLNG 3.5 Mt Isolation ponds +

investigating other options

Isolation ponds +

investigating other optionsCSG to LNG 8-12 Mt

industry

Non-CSG in the Surat 6-9 Mt

in perpetuity*

Released to the environment

* Based on public statements of other project proponents

Estimate uses an assumed average salinity across the Surat

Basin; does not include salt from unlicensed bores

The CSG to LNG industry is isolating the salt and testing alternatives,

rather than releasing direct to the environment23 |

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APLNG Project - Upstream Delivery

Presented by Adrian Lang

Project Director

Origin Operational Review and Asset Visit

20-21 May 2013

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Upstream Project Goals

• Health and Safety •Zero Harm1

• Environment and Land•Honour our Commitments2

• Safe & Operable Production System •Automation from central control room3

26 |

• Project within schedule and budget•Check estimate performed4

• Team effectiveness• Integrated commissioning and operations team5

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Upstream Operations are like a factory

Optimise

Plan

Land Access

Drill

Complete

Connect

Operate

Produce

Scale & continuous

improvement applied to

repeatable processes

reduces execution risk and

drives costs lower

PJ /

yr

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524

327

115

677

256

~844

0

200

400

600

800

1,000

1,200

Approvals Gathering (wells equivalent)

Drilling (Phase 1 requirement)

To be drilled Drilled (Spudded)

Gathering design completed Gathering lines installed

Compensation arrangements agreed Fully approved wells

Upstream development land, environmental and stakeholder

management is progressing

Gas and water gathering

Drilling and completion

Lease acquisition

(1) As at March 2013

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• Drilling and completions managed as a

manufacturing process

• Small improvements make big impacts

due to large well count

• Cost reductions leveraged through

technology and scale

• Hybrid coiled tubing and automated

drilling rigs

– Minimal disturbance leases

– Rapid deployment

– Reduced support systems

• Casing & wellhead design optimized for

low CO2 & benign formation waters

• Modularized wellhead “plug-and-play”

29 |

Drilling Completions

Upstream development implementation - Drilling and

Completion

Progress Update (March 2013):

• 256 Phase 1 operated wells spudded

• “Land bank” established enabling flexibility in work fronts

• Three Savanna hybrid coil rigs and two conventional Ensign rigs operational

• Options for further rigs are available, an additional „top-set‟ rig will be mobilised in May

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Eastern Gas Fields (Condabri/Talinga)

March 2013

Western Gas Fields (Spring Gully/Combabula)

March 2013

Upstream development implementation - Well progress

Miles

Condamine

Chinchilla

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Design Evolution – Wellheads

Spring Gully

TalingaSpring Gully

• Talinga’s wellheads have:

- 1 operator per 35 wells

- Skids completed quickly

with only 1 weld

- Electric drive

- Micro turbines

- Smaller drill pads (less

disturbance)

• Spring Gully’s wellheads have:

- 1 operator per 15 wells

- Slow install (6 welds)

- Hydra pack with oil and

service requirements

- Flexi hose which requires

maintenance

- Larger drill pad

Condabri

• Condabri wellheads have:

- Full automation

- Controlled remotely so less

field operations support

required

- Electricity to each site

- Operate by exception

- Minimal disturbance drilling

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Upstream development implementation - Gathering

• Installation of cable, gas and water High Density

Polyethylene (HDPE) pipe to wells through

trenching operations is underway

• Topography in Western areas creates longer route

lengths than anticipated

• High degree of automation on wellheads to reduce

lifecycle costs and enable remote turndown

• 3 contractors constructing simultaneously across a

wide geographical area

• Construction practices continuously being

optimised to improve HSE and productivity

outcomes

32 |

Progress Update (March 2013)

• 792 gathering well sites ready for construction

• 68 diameter kilometres of flow lines installed,

equivalent to 115 wells

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Upstream development implementation – Facilities

• 8 (out of 15 total) compressor trains arrived in Brisbane

• First 8 gas plant pre-assembled module trains shipped from Thailand, all

equipment delivered to Condabri Central for construction of first compressor train

• Construction under way for 5 out of 7 gas processing facilities and both water

treatment facility sites

• Fabrication of switchrooms in Melbourne, main transformers in China, and TEG

dehydration packages in Korea, are all on track

Condabri Central Train 2 Compressor Footing Condabri Central Water Treatment Facility Pipelines

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Design Evolution – Compressors

TalingaSpring Gully

• Talinga has a combination of

screw & reciprocating

compressors:

- Lower vibration

- Large range of suction

pressure flexibility

• Spring Gully has a 4 stage

reciprocating compressors

and gas fired engines:

- Recip. Machine Vibration

- No flexibility to inlet

conditions

Condabri

• Condabri has centrifugal

compression and will be

electrified.

• Automated to allow operation

from Brisbane control centre

• Increased reliability and lower

operating costs

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Upstream development implementation - Pipeline

• Pipeline design features: 360 km 42-inch main trunk line and 160

km lateral pipelines to gas fields with 50 year design life

• 56% complete at the end of March 2013

• Sound progress has been made to maintain the main transmission

pipeline access ahead of construction

• Nacap is commencing construction on the Wooleebee Lateral as sub

contractor while MCJV constructs the main pipeline resulting in

early completion

• All line pipe for the main pipeline procured with last delivery

shipped in March in line with schedule

• The Condabri lateral is complete and hydrotesting is underway

• Narrows Crossing construction progressing in a timely manner for

APLNG driven by early completion for QCLNG

Installation of main pipeline Narrows Crossing

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275 kV Powerlink Network on

schedule and well advanced.

“Columboola to Wandoan South”

“Columboola to Western Downs”

132 kV Network

Powerlink Contract on

schedule and well advanced

“Columboola South

Transmission Network”

`Roma

132kVEast Load

Management Scheme

Supplies early power

132 kV to Tarong

275 kV Powerlink

Contract

“Orana Substation”

132 kV Network

Powerlink contract executed, project planning well underway.

“Wandoan South to Eurombah Transmission Project”

West Early

Power Scheme

being developed

Upstream development implementation - Electrification

remains on track

Existing 132kV

New 275 kV

New 132 kV

Legend

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• Talinga Condabri System – Landowner

Irrigation Scheme

1. Water distribution to be operated by

Sunwater, a Queensland Government

entity

2. Pumping stations at Condabri and Talinga

(Monreagh)

3. Storage Dam (Monreagh) approximately

1,900 ML at Talinga

4. Access to 8 landholders with potential

for up to 15.4 GL per annum

• Reedy Creek System – Aquifer Injection

1. Injection trials underway to validate

design

2. Field pumping system to approximately

20 injection wells

3. High flow pumping to back-up injection

wells

Upstream development implementation - Water Solutions

WTF control panels

Condamine riverPongamia plant

37 |

Systems being implemented focus

on improved „beneficial use‟

compared to earlier schemes

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Condabri Development

CampsCamps

Water

Treatment

Facility &

Feed Pond

Brine

Ponds

Gas Plant

Vegetation

Buffer

Q100 Flood

Limit

Switchyard

Camps

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Upstream development implementation - status

39 |

Condabri

• 1st wells ready for commissioning

• Extensive gathering activity underway

• Early flare ready for commissioning

• Compressors in place and installation underway

• All modules in place and electrical and mechanical assembly

ongoing

• Switchyards complete

• Power energised to Condabri North, stringing to Condabri

Central underway

• Gas and water pipelines to Talinga final connections under

construction

• Monreagh dam nearing completion

• Reverse Osmosis plant construction well advanced

Reedy Creek

• Work accelerating as contractors mobilise and ramp up to

duplicate Condabri

Condabri Central – early flare scope

nearing completion

Reedy Creek – first pipe installation

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Upstream milestones Date (CY)

Pipeline manufacture 2011 and 2012

Condabri construction camp occupied June 2012

Third hybrid coil drill rig introduced mid 2012

Pipeline welding commences Q3 2012

Condabri central gas plant 50% complete Q1 2013

Fifth drill rig introduced Q1 2013

Western gas field facilities 15% complete (related to Train 2) Q2 2013

Eastern gas field facilities 70% complete (related to Train 1) Q2 2013 – on track

320 operated well drilled Q2 2013 – on track

100 diameter-kilometres of gathering installed (equivalent to 170

wells)Q2 2013 – on track

Main pipeline completion early 2014 – on track

First gas to LNG Train 1 early 2015 – on track

Milestones – Upstream project 35% complete as at March 2013

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APLNG Project – Downstream Delivery

Presented by David Hayter

Deputy Project Director, Downstream Project

Origin Operational Review and Asset Visit

20-21 May 2013

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Curtis Island has been designated as an LNG precinct with the

full support of the State and Federal governments

43 |43 |

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1. Two trains of 4.5 MTPA capacity, consisting of:

1. 6 GE LM 2500+ G4 Dry Low Emission drivers

2. Turbine inlet air chilling

3. Redesigned nitrogen reinjection units

4. Waste heat recovery

• EIS approval for four trains

2. Utilities required:

1. Power generation

2. Water and sewerage (from the mainland)

3. Air and nitrogen

4. Ground flares

3. Control Room capable of operating four trains

4. Maintenance, administrative, and warehouse

facilities which can be expanded

5. Two LNG storage tanks

1. Capacity of 160,000 m3 each

• LNG loading berth and jetty

– Suitable for ships with capacity up to 220,000 m3

• Temporary facilities set-up for construction include:

– 2,600 man camp

– Offices

– Laydown area

Curtis Island site overview

APLNG Downstream Facilities

44 |

Liquefaction of natural gas is an established technology, with project design based on the

Darwin LNG project which has operated since 2006

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Origin assurance processes around the LNG Downstream Project

Execution

Strategise

• Working with shareholders through the APLNG joint venture structure and its various sub-committees to provide direction and support to the project team

Engage

• Continuous engagement between operator and shareholders functioning as one delivery team

Execute

• Continuous presence through seconded resources into the project team and through other assurance activities in all project activity sites

Check

• Timely status check through assurance reviews and audits to determine progress and alignment of strategy and execution

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Downstream project current status - Engineering

• Overall engineering progress on the

Downstream project is ahead of

plan

• Train 1 engineering is >99%

complete

• Train 2 engineering is nearing

completion

• Monitoring of Factory Acceptance

Testing is a major activity,

including:

– GE/NP Gas Turbines &

Refrigeration Compressors

– Siemens electrical substations

– TAS inlet air chillers

Train 1 – CO2 Absorber unloaded at MOF

LNG Tank A – Roof nozzle46 |

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• Procurement is 62% complete, in line with

plan

• Structural steel fabrication continues at

China Steel Corporation, with 11,000

tonnes shipped to date

• Spools and steel continue to arrive at the

Batam module yard

• Major equipment delivered to Curtis

Island:

– All Train 1 refrigeration compressors

– Gas turbine generators for Trains 1 & 2

– CO2 absorber column

– Nitrogen & air receivers

Train 1 Refrigeration Compressor Foundations

Batam Module Yard, Indonesia

Downstream project current status - Procurement

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Downstream project current status - Construction

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MODULE FABRICATION, INDONESIA

• 8 modules completed and shipped

• 32 modules under construction

MARINE FACILITIES

• MOF operational since early 2013

• Rock & ferry causeway complete, aggregate

conveyor & ferry jetty in operation

• LNG jetty platform permanent piling in progress,

currently piling bent 8 of 26

TEMPORARY WORKERS‟ ACCOMMODATION FACILITY

AND CONSTRUCTION FACILITIES AREA

• 1,800 beds available

• Swimming pool and tavern complete

• Bechtel and APLNG construction offices occupied

• CFA training and medical facility complete

PERMANENT BUILDINGS

• Foundation works progressing for main control

admin building, fire station/medical building &

maintenance shop/laboratory

LNG TRAINS

• Train 1 refrigeration compressor table tops

complete. First two compressors set

• Major Train 1 concrete pours made for

foundations of cryo cooler, methane cold box

& dehydration/mercury removal unit

• Train 2 foundations work ongoing – methane &

propane compressor mats complete &

columns started

LNG TANKS

• Tank A: Ring #13 of shell plates installed,

welding underway. Roof approaching

completion (air raising planned for June)

• Tank B: Ring #12 complete, starting ring #13,

installing center sections of roof

• Outer wall concrete pours progressing on both

tanks

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Resourcing

• >1,900 people at Curtis Island

• >1,900 people at Batam Module Yard

• Total Curtis Island site peak approximately 3,500 personnel (two trains) starting late 2013

• Curtis Island man-hours:

1. Direct 8.3 million

2. Indirect 6.2 million

3. Sub-contract 4.8 million

• Module yard

1. Direct 8.4 million

2. Indirect 2.5 million

• Industrial relations requires constant attention

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Project Highlights

• Downstream project is on schedule

– Engineering progress is ahead of plan. Train 1 Engineering is 99%

complete and Train 2 is nearing completion

– Procurement is in line with plan. Major equipment deliveries to site

have commenced

– Construction access dredging is complete. Main shipping channel and

turning basin dredging continues

– Logistics facilities are complete. MOF and Rock & Ferry causeway are

operational

– Site accommodation village continues to expand, with >1,800 rooms

currently available

• The early, critical components that posed a significant risk to cost and

schedule – civil works on Curtis Island and the MOF – are complete

– Bechtel is responsible for all activity on Curtis Island under a fixed price

contract

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Milestones – Downstream Project 37% complete as at March 2013

Downstream Milestones Date (CY)

1st concrete LNG Tanks April 2012

1st concrete Train 1 foundations June 2012

Roll-on roll-off facility fully operational June 2012

1st occupancy of Curtis Island camp Q3 2012

Module assembly underway Q3 2012

Heavy mechanical erection start late 2012

Material Offloading Facility complete / operational early 2013

First LNG module delivery early 2013

First compression shipped to site early 2013

LNG cold box delivery late 2013

LNG cryo modules late 2013

Pre-commissioning late 2014 – on track

First LNG from Train 1 mid 2015 – on track

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Port of Gladstone Overview

Gladstone

Brisbane

FLNE

CELL 3

GOONDOON

STREET

BENSTED

ROAD

MARINA &

RG TANNA

APLNG

CURTIS ISLAND

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Fishermans Landing

APLNG

Cell 3 area

APLNG FLNE

RO/RO

APLNG FLNE

Passenger Terminal

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APLNG Aggregate

Conveyor

APLNG FLNE

Platform

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Fishermans Landing Northern Expansion (FLNE)

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Ferry

Ro/Ro

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Curtis Island Site, March 2013

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Curtis Island, In Construction – March 2013

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Tank B

Tank A

Train 2

Train 1MOF

Ferry & Rock

Causeway

RO/RO

Ramp

Construction

Facilities

Control &

Maintenance Utilities

Accommodation

Village

LNG

Jetty

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LNG Tanks – March 2013

LNG Tank A Roof

LNG Tank A - Installation of 13th ring and

compression bar

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LNG Tanks – April 2013

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LNG Tanks A and B

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Material Offloading Facility – March 2013

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Train 1 – CO2 Absorber unloaded at MOF

First module moving from barge onto MOF

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Refrigeration Compressor Area – April 2013

Train 1 Refrigeration compressor building, with methane compressor turbine housing set

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Refrigeration Compressor Area – March 2013

Train 1 – Ethylene compressor table top

concrete pour

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Train 1 – Stripping shoring at Propane

compressor table top

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Train 1 – March 2013

Concreting Methane Cold Box foundation

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Pouring Cryo Cooler foundation

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LNG Modules

Barge with first 4 modules arriving at MOF –

March 2013

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First 4 modules set on foundations – April 2013

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Modularisation Yard in Indonesia

Moving Coolers to Phase IV Staging AreaDelivery of Ethylene Purge Drum

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Modules ready for Barge Shipment #3, forecast June 2013

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Thank you

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