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Terang Sirasun BaturGas Development Project
Four Seasons Hotel Jakarta, Indonesia
Tuesday, November 22, 2005
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• Kangean PSC acquired by EMP from BP in August 2004• Terang field discovered in 1982, Sirasun in 1993 and Batur in
1995• The TSB reserves of 1.6 TCF were certif ied by “ D&M” in May
1995• Kangean PSC Extension approved in December 2004• Development of TSB fields i s expected to deliver gas to East
Java market starting from 4 th Q 2007• Development strategy: Phase-1 with target of production in
4 th Q 2007 and Phase-2 with target of production in the 4 th Q2009.
• Plan Of Development (POD) approved in October 2005• Front End Engineering Design completed in October 2005
IntroductionIntroduction
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Kangean PSC Development Project
2
Iga ngan - 1
Pa gerungan 3 1 24
Palung - 1
S. Sepanjang -1
Sepapan -1
JS 53A
0 20 Km.
SEPANJANG
5E. Sa kala - 1
SAKALA
J S 5 3 B - 1
115 o 00' 115 o 30' 116 o 00'
Arya - 1
1
Sirasun - 2
116 o 30'
KANGEAN
PALIAT
W. K a n ge a n1
2 3
Sidu la ng - 1
Sepanjang isl . - 1 Kiau - 1 JS 25 - 1
Saka la - 1
2
1
Kemirian - 1
600'
BNMP 0318a - E. Somantri
07o 00'
07o 30'
1000'
1500'
JS 50 -1
Kubu - 1
PA G ER UN G A N
Batur
Terang - 1
3 0 0 0
PAGERUNGAN
DEPELOP M ENT
TERANG -SIRASUN
AREASouth Saubi
Karan g Takat
South Celukan
E. Sakal a
West Kangean
SepanjangIsland
JS53East Spur
Pagerungan / TSB
Gas Discoveries
Oil Discoveries
Prospect & Leads
PipelineProposed Pipeline
2
Iga ngan - 1
Pa gerungan 3 1 24
Palung - 1
S. Sepanjang -1
Sepapan -1
JS 53A
0 20 Km.
SEPANJANG
5E. Sa kala - 1
SAKALA
J S 5 3 B - 1
115 o 00' 115 o 30' 116 o 00'
Arya - 1
1
Sirasun - 2
116 o 30'
KANGEAN
PALIAT
W. K a n ge a n1
2 3
Sidu la ng - 1
Sepanjang isl . - 1 Kiau - 1 JS 25 - 1
Saka la - 1
2
1
Kemirian - 1
600'
BNMP 0318a - E. Somantri
07o 00'
07o 30'
1000'
1500'
JS 50 -1
Kubu - 1
PA G ER UN G A N
Batur
Terang - 1
3 0 0 0
PAGERUNGAN
OPTIM IZATION
TERANG -SIRASUN South Saubi
Karan g Takat
South Celukan
E. Sakal a
West Kangean
SepanjangIsland
JS53East Spur
Pagerungan / TSB
Gas Discoveries
Oil Discoveries
Prospect & Leads
PipelineProposed Pipeline
DEVELOP M ENT
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Terang Sirasun Batur Fields Map
100 m ---------------------------------- 200 m< 100 m > 200 mWater Depth:
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Terang 58%
Batur 4%
Sirasun 38%30 km
12 km
% Reserve of Each% Reserve of Each FieldField
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GeohazardGeohazard MapMap
Potential Geohazard:
• Surface Fault• Seismic Activity• Landslide• Shallow Gas
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TSB Well Trajectory Plan
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0
50
100
150
200
250
300
2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027 2029
G a s
S a l e s ,
M M S C F D
Daily Contract Quantity
Gas ProductionGas Production ProfileProfile
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(-100 m)
(-200 m)
TSB DevelopmentTSB Development OverviewOverview
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• Low Pressure Reservoir • 98+% Methane, no H 2S, min. CO 2• Design Life 15 yrs• Facili ty Design Capacity 330 MMscfd• ‘Fit for Purpose’ and ‘Proven Design’•
High Reliability & Availabili ty• Min. suction pressure 150 psig & dischargepressure 1300 psig• Compliance with International Standards/Codes• For Phase-I: Water depth at Terang is 100 meter
Key Design ParametersKey Design Parameters
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Phase-1
Phase-2
EPC ‘Hull & Mooring’
PO ‘Compressor’
PO ‘Subsea System’
EPCI ‘Subsea Facilit ies& Integration’
EPCI ‘Topside Facilit y’
TSB DevelopmentTSB Development Strategy: Phase-IStrategy: Phase-I
Drill 5 Wells
Hot Tap
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Scope :Supplies the following :• Subsea Wellhead & Trees•
Subsea control system• Dynamic & Static Umbilical• Manifold• Topside Control Equipment
PO Subsea SystemPO Subsea System
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FUTURE
Scope :Two units Gas Turbine Compressors c/w Turbine Control System.
HPC1
HPC2
HP Header MP Header
Prod Separator
P-1P-2
V-1 V-2
GasToDehy’d
LP Header
P-4
V-4
V -3
MPC 1
MPC 2
LLP Header
LPC 1
LPC 2
V-5
PO TurbinePO Turbine CompressorCompressor
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Hull Structural Plan
EPC Hull & Mooring SystemEPC Hull & Mooring System
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Process Flow Diagram
EPCI TopsideEPCI Topside FacilityFacility
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Terang
Batur Sirasun
Subsea Production Facilities Lay-out
EPCI Subsea FacilityEPCI Subsea Facility
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Subsea Control System Layout
EPCI Subsea FacilityEPCI Subsea Facility
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SCOPE EPCI
'TOPSIDE'
EPC 'HULL
& MOORING' PO 'COMPR.'
EPCI
'SUBSEA'
PO
'SUBSEA'
COMPRESSOR X X
PROCESS EQUIPMENT X X
HUL L X X
MOORING SYSTEM X X
SUB SEA CTRL SYSTEM X X X
TOPSIDE SUBSEA CTRL EQUIPMENTX X X
SUB SEA FL OWL INE SYSTEM X X
Interface Matrix ofInterface Matrix of FacilityFacility
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Manageability
React Infl uence
R i s k
L o w
M e d
H i g h
MedLow High
Legend:
1. ProjectOrganization7. GOI Approval .
10. Bidde rs participation
5. Interface OffshoreIns tallation (Fa c vs. Drilling)
11. availability oflocal fabricator
3. Inter departme ntalcommunication
/suppo rt
4. P roject/ C ontract Integration
Lega l Standing
8. Rig Availability
Risk & Disciplinecompetency
Externalrelationship
EM P Culture& InternalRelationship
2. Com p policy & procedures
6. Contractorcompetency /capa city
9. EJGP Integrity
Project DevelopmentProject Development Risk Risk
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Project ScheduleProject Schedule
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ProjectProject CostCost
Total Estimated C ost: USD 400 million
Phase-I Estimated C ost: USD 275 million
Phase-II Estimated C ost: USD 125 million
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Company ExpectationCompany Expectation
• No LTA• Gas-in before December 2007• Project executed within approved budget
• Facility performance meets design requirement• Appreciate local content• Maximize gas recovery
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