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Transcript of APLNG CSG PRODUCTION – ORG REVIEW AND ASSET · PDF fileSubject APLNG CSG PRODUCTION ......
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 – [email protected]
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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 …
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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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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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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
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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
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• 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”
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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
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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
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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
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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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