indonesia seminar eor
DESCRIPTION
Indonesia Seminar EORTRANSCRIPT
-
1LEMIGASLEMIGAS
GAS (& OIL) FIELDS DEVELOPMENTGAS (& OIL) FIELDS DEVELOPMENT&&
EOR/IOR TECHNOLOGIES EOR/IOR TECHNOLOGIES (A LESSON FROM INDONESIA)(A LESSON FROM INDONESIA)
LEMIGASLEMIGAS
0
10,000
20,000
30,000
2D (Planning) Km 23,548 19,015 8,665 8,655 13,494 7,054 8,672
2D (Actual) Km 17,156 14,599 2,167 5,190 13,514 15,854 8,422
3D (Planning) Km 11,796 3,749 6,149 9,298 1,840 18,373 4,897
3D (Actual) Km 10,240 6,632 4,077 8,757 2,131 2,749 5,459
1998 1999 2000 2001 2002 2003 2004
SEISMIC ACTIVITY IN INDONESIA
LEMIGASLEMIGAS
0
20
40
60
80
Well
s
Actual Discovery Success Ratio (%)
Actual 60 47 56 51 47 39 16Discovery 17 17 25 16 21 16 8Success Ratio (%) 28 36 44 31 44 41 50
1998 1999 2000 2001 2002 2003 2004
WILDCAT DRILLING IN INDONESIA
LEMIGASLEMIGAS
PROGRAMME VS REALIZATIONE&P DRILLINGS
PERIOD: 2000 - 2004
0
200
400
600
800
1000
1200
1400
Wel
l num
ber
Exploration Planning 144 117 112 114
Exploration realization 71 87 75 54 19
Exploitation Planning 1137 1112 1241 938 1069
Exploitation Realization 890 910 837 815 504
2000 2001 2002 2003 2004
-
2LEMIGASLEMIGAS
POLICIES TO INCREASE RESERVES AND PRODUCTION POLICIES TO INCREASE RESERVES AND PRODUCTION
DEVELOPING & APPLIED TECHNOLOGY: TO MAINTAIN & TO DEVELOPING & APPLIED TECHNOLOGY: TO MAINTAIN & TO INCREASE PRODUCTION AND RESERVES AT 1 MBOPD AND 10 INCREASE PRODUCTION AND RESERVES AT 1 MBOPD AND 10 MMBBL RESPECTIVELYMMBBL RESPECTIVELY
OPERATING COST (E&P) EFFICIENCY OPERATING COST (E&P) EFFICIENCY
DISCOVERY NEW RESERVES, INCLUDING FRONTIER AREA DISCOVERY NEW RESERVES, INCLUDING FRONTIER AREA (DEEP WATER DEPOSIT (DEEP WATER DEPOSIT SEA WATER DEPTH 3500 FEET), e.g. IN SEA WATER DEPTH 3500 FEET), e.g. IN EAST KALIMANTANEAST KALIMANTAN
INCREASING PRODUCTION BY APPLYING FRACTURING, INCREASING PRODUCTION BY APPLYING FRACTURING, ACIDIZING, ACIDIZING, WATER FLOOD, STEAM FLOOD OR POLYMER.WATER FLOOD, STEAM FLOOD OR POLYMER.
LEMIGASLEMIGAS
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
PRO
DU
CTI
ON
(MB
OP
D)
Historical Historical OutputOutput
Projection to 2015Projection to 2015
No Operating Effort Profile
No Operating Effort Profile
On Going Field Development
On Going Field Development
Marginal FieldsMarginal Fields
Brown FieldsBrown Fields
Expected New Fields Developments
Expected New Fields Developments
New Potential DevelopmentNew Potential Development
Maintenance Optimalization
Maintenance Optimalization
New Potential Developments, Prod. opportunity of expected
fields, result from discoveries in 20052007.
POD submitted by year 2007/2008.
Prod. Starting from 2009/2011
INDONESIA OIL PRODUCTION PROFILE 1994-2015CASE-1
INDONESIA OIL PRODUCTION PROFILE 1994INDONESIA OIL PRODUCTION PROFILE 1994--20152015CASE-1
LEMIGASLEMIGASTERM AND CONDITION OF THE BLOCKS TERM AND CONDITION OF THE BLOCKS FOR THE FIRST ROUND BIDDING 2005FOR THE FIRST ROUND BIDDING 2005
GROSS PRODUCTION
Investment Credit
Max. Cost Recovery : 100%
EQUITY TO BE SPLIT
FTP Max. 20%
INDONESIA SHARE
CONTRACTOR SHARE
DMO Fee
DMO Max.25%
Tax 44%
INDONESIA TAKE CONTRACTOR TAKE
Taxable Income
(+) (-)
(+)(-)
(-)(+)
(+)
(+)
(-)
(-)(+)
(-)
FLOW OF REVENUE OF INDONESIA PSC (OLD)
FLOW OF REVENUE OF INDONESIA PSC (NEW)
GROSS PRODUCTION
Investment Credit
Max. Cost Recovery : 100%
EQUITY TO BE SPLIT
FTP Max. 10%
INDONESIA SHARE
CONTRACTOR SHARE
DMO Fee
DMO Max.25%
Tax 44%
INDONESIA TAKE CONTRACTOR TAKE
Taxable Income
(+) (-)
(+)(-)
(-)(+)
(+)
(+)
(-)
(-)
(+)
(-)
-
3LEMIGASLEMIGAS
135.3
117.9
4,533.5
886.8
738.0259.4
407.7
920.1
100.1
Aceh (NAD)
CentralSumatera
SouthSumatera
Irian Jaya (Papua)
OIL RESERVES (MM STB)
Natuna
East Java
East Kalimantan
North Sumatera
West Java
Maluku
PROVEN = 4,300.68 MM STBPOTENTIAL = 3,988.26 MM STBTOTAL = 8,288.94 MM STB
109.1
South Sulawesi
81.1
Indonesia Oil Reserves (incl. Condensate)Indonesia Oil Reserves (incl. Condensate)Proven & Potential, As Of 01Proven & Potential, As Of 01--0101--20042004
(Updated Sep 04)(Updated Sep 04)
LEMIGASLEMIGAS
8.670.78
8.21
24.47
6.04
4.46
54.20
47.39
4.36 23.92
ACEH (NAD)
SUMATERACENTRAL
SOUTH SOUTH SULAWESI
IRIAN JAYA (PAPUA)
GAS RESERVES (TCF)
NATUNA
EAST JAVA
SUMATERA
EAST KALIMANTANNorthSUMATERA
WEST JAVA
PROVEN = 94.78 TCFPOTENTIAL = 87.73 TCFTOTAL = 182.50 TCF
Indonesia Gas ReservesIndonesia Gas ReservesProven & Potential, As Of 01Proven & Potential, As Of 01--0101--20042004
Last Updated Sep 04Last Updated Sep 04
LEMIGASLEMIGAS
Proven
Potential
0
2,000
4,000
6,000
8,000
10,000
12,000
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
MMST
BMM
STB
Indonesia Oil Reserves (incl. Condensate)Indonesia Oil Reserves (incl. Condensate)Proven & Potential, ( 1980 Proven & Potential, ( 1980 -- 2004)2004)
LEMIGASLEMIGAS
Proven
Potential
0
20
40
60
80
100
120
140
160
180
200
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
TCF
TCF
Indonesia Gas ReservesIndonesia Gas ReservesProven & Potential, ( 1980 Proven & Potential, ( 1980 -- 2004)2004)
-
4LEMIGASLEMIGAS
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,000
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
(BCF)(BCF)
TotalTotal
VicoVico
ExxonMobilExxonMobil
PertaminaPertamina
UnocalUnocalBP Ind.BP Ind.
Proven Gas ReservesProven Gas ReservesFrom Producing Fields, ( 1966 From Producing Fields, ( 1966 -- 2004)2004)
LEMIGASLEMIGAS
DAERAH
01. ACEH 3.896,36 2.697,35 1.199,0102. NORTH SUMATERA 727,59 368,29 359,3003. CENTRAL & SOUTH SUMATERA 17.475,61 9.953,46 7.522,1504. WEST JAVA 5.190,07 3.318,00 1.872,0705. CENTRAL JAVA 105,66 - 105,6606. EAST JAVA 4.289,45 2.424,83 1.864,6207. EAST KALIMANTAN 31.813,69 13.516,97 18.296,7208. NATUNA 52.081,36 4.451,99 47.629,3709. SOUTH SULAWESI 3.653,99 156,38 3.497,6110. PAPUA 14.781,71 1.945,49 12.836,22
TOTAL INDONESIA 134.015,49 38.832,76 95.182,73
2P2P
COMMITTED DEMAND BALANCE
REMAINING RESERVES
NOTE :2 P = Proven + ProbableCommitted demand = Total requirement based on contract GSPA / GSABalance = Remaining reserves - Committed demandCommitted demand include contracts GSPA / GSA 2003 - 2004
Source : BP MIGAS
COMMITTED GAS DEMAND INDONESIACOMMITTED GAS DEMAND INDONESIA
LEMIGASLEMIGAS
U T ILIZ A T ION M M SC FD ( %)FER TILIZER / PETR OC HEM 6 3 0 ,5 8 ,1R EF IN ER Y 8 0 ,6 1,0LPG 2 8 ,5 0 ,4PGN 2 3 6 ,4 3 ,0C EM EN T 9 ,4 0 ,1ELEC T R IC ITY 6 9 6 ,5 8 ,9KR A KA T A U STEEL 78 ,9 1,0OT HER IN D U ST R IES*) 3 2 4 ,9 4 ,2OW N U SE 1.0 4 8 ,2 13 ,4LOST/ FLA R IN G 4 9 1,4 6 ,3TOTA L D OM ESTIC 3 .6 2 5,3 4 6 ,4
LN G 4 .0 8 2 ,0 52 ,2LPG 6 ,6 0 ,1GA S 10 4 ,8 1,3TOTA L EX POR T 4 .19 3 ,4 53 ,6
GAS UTILIZATION IN INDONESIA(YEAR 2001)
PROD7,80 BSCFD
PSC7,04 BSCFD
Perta
min
a0,
76 B
SCFD
53,6%
46,4%Domestic
Export
Source : DG Oil and Gas
LEMIGASLEMIGAS
DOMESTIC GAS PRICE(Per MMBTU)
0
0.5
1
1.5
2
2.5
3
3.5
FERTILIZERFERTILIZER ELECTRICITYELECTRICITY PGNPGN KSKS8080 9090 20002000
-
5LEMIGASLEMIGASGAS PIPELINE INFRASTRUCTUREGAS PIPELINE INFRASTRUCTURE
IN INDONESIAIN INDONESIA
1.1. Master plan of the National and Distribution Network of Natural Master plan of the National and Distribution Network of Natural
Gas Indonesia (Indonesia Integrated Gas Pipeline Master Plan)Gas Indonesia (Indonesia Integrated Gas Pipeline Master Plan)
2.2. Current Bidding of Gas Transmission Pipeline Infrastructure in Current Bidding of Gas Transmission Pipeline Infrastructure in
Java Island :Java Island :
-- CirebonCirebon SemarangSemarang 230 km 350230 km 350--500 MMSCFD500 MMSCFD
-- GresikGresik SemarangSemarang 250 km 350250 km 350--500 MMSCFD500 MMSCFD
3. Forthcoming Bidding of Gas Transmission Pipeline Infrastructu3. Forthcoming Bidding of Gas Transmission Pipeline Infrastructure :re :
-- East Kalimantan East Kalimantan Central Java 1220 km 700 Central Java 1220 km 700 1000 MMSCFD1000 MMSCFD
-- MuaraMuara BekasiBekasi CirebonCirebon 220 km 500 220 km 500 700 MMSCFD700 MMSCFD
LEMIGASLEMIGAS
Kategori 1: Open Access (Tidak Tender)
Pipeline rencana (plan) - Persetujuan Prinsip Pembangunan- Persetujuan Prinsip, telah terpasang
Kategori 2: Dedicated HilirPipeline yang telah ada (existing)Pipeline rencana (plan)
Kategori 3: Dedicated HuluPipeline yang telah ada (existing)Pipeline rencana (plan)
Wilayah jaringan distribusirencana (plan)
Kategori 1: Open AccessPipeline yang telah ada (existing)Pipeline rencana (plan), Tender
Wilayah jaringandistribusi yang telah ada
Wilayah jaringandistribusi
( l ) T d
LEGEND Sumber GasKonsumenKompresor
Regulator
KotaKilang
Petrokimia, Pabrik BajaPower Plant
Batas Wilayah
- Persetujuan Prinsip, telah terpasang
MASTER PLAN OF THE NATIONAL TRANSMISSION & DISTRIBUTION NETWORK OF NATURAL GAS
INDONESIA(Based on BPH (Based on BPH MigasMigas data)data)
LEMIGASLEMIGAS
OIL CONTAINING RESERVOIR
Cumulative Prod.
Remaining Reserves
Oil Reserves at primary recovery
Oil Potential at IOR/EOR stages
Original OIL In Place (OOIP)
LEMIGASLEMIGAS
DISTRIBUTION OF OIL RESERVES & DISTRIBUTION OF OIL RESERVES & PRODUCTION IN INDONESIAPRODUCTION IN INDONESIA
Cummulative prod. 19,916,408,300 STB
Remaining Primary Recovery4,782,290,700 STB
Target of EOR36,450,017,600 STB
OOIP of OIL FIELDS IN INDONESIA 61,148,716,600 STB
-
6LEMIGASLEMIGAS
INCENTIVES FOR EOR PROJECTINCENTIVES FOR EOR PROJECT
JOB SCHEME:JOB SCHEME: DMO of Incremental Oil (export oil price applied for first 5 yeaDMO of Incremental Oil (export oil price applied for first 5 year)r) INVESTMENT CREDIT (17%)INVESTMENT CREDIT (17%)
PSC SCHEME:PSC SCHEME: DMO of Incremental Oil (export oil price applied for first 5 yeDMO of Incremental Oil (export oil price applied for first 5 year)ar) INVESTMENT CREDIT (20% for Capital cost relating to EOR OperatioINVESTMENT CREDIT (20% for Capital cost relating to EOR Operation)n)
LEMIGASLEMIGAS
DEVELOPMENT OF EOR METHODS DEVELOPMENT OF EOR METHODS (GENERAL APPLICATION)(GENERAL APPLICATION)
1. INJECTION OF GAS (NITROGEN) 1. INJECTION OF GAS (NITROGEN) 2. INJECTION OF HYDROCARBON GAS2. INJECTION OF HYDROCARBON GAS3. INJECTION OF GAS (CO3. INJECTION OF GAS (CO22))4. INJECTION OF GAS IMMICIBLE4. INJECTION OF GAS IMMICIBLE5. INJECTION OF MICELAR5. INJECTION OF MICELAR6. INJECTION OF POLYMER6. INJECTION OF POLYMER7. INJECTION OF ASP (ALKALIN7. INJECTION OF ASP (ALKALIN--SURFACTANSURFACTAN--POLYMER)POLYMER)8. COMBUSTION8. COMBUSTION9. INJECTION OF STEAM9. INJECTION OF STEAM10. INJECTION OF MICROBIAL10. INJECTION OF MICROBIAL
LEMIGASLEMIGAS
STAGE OF EOR EVALUATIONSTAGE OF EOR EVALUATION Screening EORScreening EOR Laboratories studyLaboratories study Reservoir SimulationReservoir Simulation Economic studyEconomic study Pilot ProjectPilot Project Full scaleFull scale
LEMIGASLEMIGAS
ViscosityViscosity GravityGravity CompositionComposition Oil SaturationOil Saturation Formation TypeFormation Type Net ThicknessNet Thickness Ave. PermeabilityAve. Permeability DepthDepth TempTemp
Reservoir Parameters METHOD OF EOR Nitrogen and Flue Gas Hydrocarbon CO2 Immiscible gas Micellar/ASP/Alkaline Polymer Combustion Steam Microbial
Choice ofMethods
Screening on EOR MethodsScreening on EOR Methods
-
7MICROBIAL MICROBIAL INJECTIONINJECTION
LEMIGASLEMIGAS
EVALUATION OF MICROBIAL INJECTIONEVALUATION OF MICROBIAL INJECTION
Study of MEOR in the PERTAMINA Oil Study of MEOR in the PERTAMINA Oil FieldField
Study of Lemigas MEOR Technology Study of Lemigas MEOR Technology Application in Application in TanjungTanjung Oil Field (Talisman Oil Field (Talisman Ltd)Ltd)
LEMIGASLEMIGAS
BIOPRODUCTS & MEOR MECHANISM
) Bio-solvents: Reducing viscosity, increasing effective permeability, dissolving oil
) Bio-surfactant: Reducing inter-facial strength) Biomass: Plugging (selective/non-selective), changing in rock
wettability) Bio-gas (CO2, CH4, H2): Reducing viscosity, Oil swelling,
increasing permeability and reservoir pressure) Bio-polymer: Controlling mobility, plugging (selective/non-selective ) Bio-acid: Increasing poroperm of carbonate reservoirs
LEMIGASLEMIGAS
METHODE of INJECTIONMETHODE of INJECTION
Nutrition InjectionNutrition Injection Potential Potential mikrobialmikrobial InjectionInjection
-
8LEMIGASLEMIGAS
0
5
10
15
20
25
30
35
0 20 40 60 80TIME (Daily)
0
50
100
150
200
250
300
350
400
OIL PRODUCTION/DAY
CUMMULATIVE OIL PROD.
Barrel Barrel/day
OIL PRODUCTION PERFORMANCEMEOR IN LDK- 132 WELL
STEAM INJECTIONSTEAM INJECTION
LEMIGASLEMIGAS
Mature Steamflood Behavior
DURI FIELD EXAMPLE
Steam cut in Nov 2003
Steam cut in May 2001
LEMIGASLEMIGAS
0
100
200
300
400
71 73 75 77 79 81 83 85 87 89 91 93 95 97 99 '01
Steamflood
Primary
RF = 50RF = 50--80%80%
RF = 8-11%
MBOPD
Duri Field Production HistoryDuri Field Production History
15
-
9LEMIGASLEMIGAS
Started production in 1975 under natural depletion.Started production in 1975 under natural depletion.
Started water injection in 1978 then full scale of Started water injection in 1978 then full scale of water injectionwater injection in 1980.in 1980.
Started Started 11stst phasephase lean gas injection in 1995 & lean gas injection in 1995 & 22nd nd phasephase in 2000.in 2000.
HANDIL FIELD EXAMPLEHANDIL FIELD EXAMPLE
LEMIGASLEMIGAS
Oil reserves statusOil reserves statusOOIP (OOIP (MMstbMMstb) / Oil Initial Reserves () / Oil Initial Reserves (MmstbMmstb))
1P1P 17001700 / / 8558552P2P 1803 1803 // 893893
PRODUCED END 2002 :PRODUCED END 2002 :818 818 MmstbMmstb96 % of 1P Initial reserves 96 % of 1P Initial reserves 92 % of 2P Initial reserves92 % of 2P Initial reserves
LEMIGASLEMIGAS
Gas reserves statusGas reserves status
IGIP(TCF)IGIP(TCF) / Gas Initial Reserves (TCF)/ Gas Initial Reserves (TCF)
1P1P 3.031 3.031 / / 2.0552.0552P2P 3.214 3.214 // 2.1752.175
PRODUCED END 2002 :PRODUCED END 2002 : 1.577 TCF1.577 TCF77% of 1P Initial Reserves77% of 1P Initial Reserves73% of 2P Initial Reserves73% of 2P Initial Reserves
LEMIGASLEMIGAS
HandilHandil Cumulative ProductionCumulative Production
Oil cumulative at end 2002 : 818 Oil cumulative at end 2002 : 818 MMstbMMstbCum. Oil natural depletionCum. Oil natural depletion : 261 : 261 MMstbMMstb ( 32 %)( 32 %)Cum. Oil Water InjectionCum. Oil Water Injection : 549 : 549 MMstbMMstb ( 67 %)( 67 %)Cum. Oil IORCum. Oil IOR : 8 : 8 MMstbMMstb ( 1 %)( 1 %)
6 6 MMstbMMstb ((11stst phasephase) + 2 ) + 2 MMstbMMstb ((22ndnd phasephase). ).
-
10
WATER WATER INJECTIONINJECTION
LEMIGASLEMIGASWater injectionWater injection
Water injection started up in OctWater injection started up in Oct--1978.1978.
Full scale water injection started up in Full scale water injection started up in year 1980.year 1980.
Water injection to 81 reservoirs (1060 Water injection to 81 reservoirs (1060 MMbblMMbbl) in MAIN zone.) in MAIN zone. NpNp @Dec02 = 549 @Dec02 = 549 MMbblMMbbl (RF = 52%)(RF = 52%)
Prolong the oil production plateau from Prolong the oil production plateau from the injected reservoirsthe injected reservoirs
LEMIGASLEMIGASReservoir 19Reservoir 19--0N 0N peripheral water injectionperipheral water injection
HKA442
OOIP=110
HP212
HSA326 GI
H316 HD414
H417HD319
HJ520
HJ525
HA3
HP410
HT228
HT225
HAA443
HS429HZB626
H811
H501H401
HTC219
HT220
HT1
LEMIGASLEMIGASHANDIL PRODUCTION HANDIL PRODUCTION HISTORYHISTORY
0
20,000
40,000
60,000
80,000
100,000
120,000
140,000
160,000
180,000
200,000
J-74
J-75
J-76
J-77
J-78
J-79
J-80
J-81
J-82
J-83
J-84
J-85
J-86
J-87
J-88
J-89
J-90
J-91
J-92
J-93
J-94
J-95
J-96
J-97
J-98
J-99
J-00
J-01
J-02
Date
Oil
rate
(bop
d)
water rate2nd IOR1st IORWI
START WATER INJECTION
START 1st IOR
START 2nd IOR
-
11
IOR: LEAN GAS IOR: LEAN GAS INJECTIONINJECTION
LEMIGASLEMIGASHANDIL PRODUCTION HANDIL PRODUCTION HISTORYHISTORY
0
20,000
40,000
60,000
80,000
100,000
120,000
140,000
160,000
180,000
200,000
J-74
J-75
J-76
J-77
J-78
J-79
J-80
J-81
J-82
J-83
J-84
J-85
J-86
J-87
J-88
J-89
J-90
J-91
J-92
J-93
J-94
J-95
J-96
J-97
J-98
J-99
J-00
J-01
J-02
J-03
Date
Oil
rate
(bop
d)
2nd IOR1st IORWIprimary
START WATER INJECTION
START 1st IOR
START 2nd IOR
LEMIGASLEMIGASHANDIL PRODUCTION HANDIL PRODUCTION HISTORYHISTORY
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,000
J-74
J-75
J-76
J-77
J-78
J-79
J-80
J-81
J-82
J-83
J-84
J-85
J-86
J-87
J-88
J-89
J-90
J-91
J-92
J-93
J-94
J-95
J-96
J-97
J-98
J-99
J-00
J-01
J-02
J-03
Date
Oil
rate
(bop
d) IOR 2nd phaseSTART WATER INJECTION
START 2nd IOR
LEMIGASLEMIGAS
THANK YOU FOR YOUR ATTENTIONTHANK YOU FOR YOUR ATTENTION
-
12
LEMIGASLEMIGAS
PERTAMINA SHARE OF COST EXPENSEPERTAMINA SHARE OF COST EXPENSE
CONTRACTOR SHARE OF COSTS EXPENSE
CONTRACTOR SHARE OF COSTS EXPENSE
NET PERTAMINA PROFIT
NET PERTAMINA PROFIT
NET PERTAMINA PROFIT
NET PERTAMINA PROFIT
NET CONTRACTOR PROFIT
NET CONTRACTOR PROFIT
REIMBURSEMENT OF PERTAMINA SHARE OF
NON CAPITAL COSTS PLUS 30% UPLIFT
REIMBURSEMENT OF PERTAMINA SHARE OF
NON CAPITAL COSTS PLUS 30% UPLIFT
GOVERNMENT TAX
GOVERNMENT TAX
REIMBURSEMENT OF PERTAMINA SHARE OF NON CAPITAL COSTS
PLUS 30% UPLIFT
REIMBURSEMENT OF PERTAMINA SHARE OF NON CAPITAL COSTS
PLUS 30% UPLIFT
CONTRACTOR ENTITLEMENTCONTRACTOR ENTITLEMENT
PERTAMINA ENTITLEMENTPERTAMINA
ENTITLEMENT
EQUITY TO BE SPLIT
EQUITY TO BE SPLIT
GROSS REVENUEGROSS REVENUE
50%50% 50%50%
85%85%
65%65% 48%48%
Max.Max. 65%65%
71.1538%71.1538% 28.8642%28.8642%
JOINT OPERATING BODY (JOB)JOINT OPERATING BODY (JOB)EOR CONTRACT SCHEMEEOR CONTRACT SCHEME
(BETWEEN PERTAMINA & CONTRACTOR)(BETWEEN PERTAMINA & CONTRACTOR)
SOURCE: EOR SYMPOSIUM, 1990SOURCE: EOR SYMPOSIUM, 1990