COCO UTILIZATION FOR EORUTILIZATION FOR EORCOCO22 UTILIZATION FOR EORUTILIZATION FOR EORAT OIL FIELDS IN INDONESIAAT OIL FIELDS IN INDONESIAAT OIL FIELDS IN INDONESIAAT OIL FIELDS IN INDONESIA

SUGIHARDJOSUGIHARDJO

Research and Development Centre for Oil and Gas Technology Research and Development Centre for Oil and Gas Technology “LEMIGAS”“LEMIGAS”

OutlineOutline

BackgroundBackgroundBackgroundBackground

COCO22 SourcesSources22

Oil Fields SelectionOil Fields Selection

Laboratory EvaluationLaboratory Evaluation

Simulation StudySimulation StudySimulation Study Simulation Study

Plan for ImplementationPlan for Implementationpp

ConclusionsConclusions

2LEMIGAS

BackgroundBackgroundBackgroundBackground

World EnergyWorld Energy--Related CORelated CO22 EmissionsEmissionsby Fuel Typeby Fuel Type

The rising of CO2emissions:

The Increasing Petroleum Industry The heavy reliance on fossil fuelsDeforestationPopulation and economic growth

3Source: IEA - International Energy Outlook 2008

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BackgroundBackground (cont’d)gg

The declining of oil productionin IndonesiaRemaining in IndonesiaGOI‘s oil production target for 2010 is only 1.1 Million Bpd

gReserves of

Primary Recovery4.8 BSTB

8% 2010 is only 1.1 Million BpdDepleted oil and gas reservoirs Cummulativ

e 19.9 BSTB32.6%

4Total OOIP: 61.1 BSTB

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BackgroundBackground (cont’d)gg700 Peak 1995Peak 1995Peak 1977Peak 1977

Plateau StagePlateau Stage

500

600

400

500

MilMilOther PSC’sOther PSC’s

300

llion barrellion barre

Other PSC’sOther PSC’s

100

200

elsels

Chevron Pacific Chevron Pacific

0

66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06 07

IndonesiaIndonesia

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BackgroundBackground (cont’d)IOR C tIOR C tIOR ConceptsIOR Concepts

Incremental secondary

Incremental

Injection WellsInjection WellsExtrapolated primary Extrapolated 

secondary

Incremental Tertiary

Producing WellsProducing Wells

Primary phase

Secondary phase

Tertiary phase(EOR)

y

Effort to force Effort to force dd ldd l

WaterWater

GasGasadditional additional petroleum out of petroleum out of the pores in thethe pores in the

SteamSteam

ChemicalChemical6

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the pores in the the pores in the reservoir rockreservoir rock

Chemical Chemical TechnologyTechnology

88Source SPE

BackgroundBackground (cont’d)

Advantages of COAdvantages of CO22 EOREOR■ Dramatic Improvement of Oil Recovery■ Dramatic Improvement of Oil Recovery

■ CO2 is Ultimate Injectant with Proven Effects／Superior

to Gas & Waterto Gas & Water

Ultimate Oil Recovery (Typical)

・ Secondary Recovery 30 % of OOIP↓

CO I j ti 45 % f OOIP

■ Saving Natural Gas Consumption

■ E i l d E i Eff

・ CO2 Injection 45 % of OOIP

■ Environmental and Economic Effect

Reduction of CO2Emission New Initiative (Kyoto Protocol)

7LEMIGAS

CO2 SourcesCO2 SourcesCO2 SourcesCO2 SourcesDepleted Oil Reservoirs

PHILIPINES

Bontang LNG Plant

NatunaNatuna

South South SumatraSumatra

East KalimantanEast Kalimantan

Storage Capacity: 38 152 MtCOSumatraSumatra Storage Capacity: 38 – 152 MtCO2

Oil Recovery: 265 – 531 Million bblCO2 Separation

West JawaWest Jawa

8Storage Capacity: 18 – 36 MtCO2

Oil Recovery: 84 – 167 Million bbl

Project Activity DiagramProject Activity Diagramoject ct ty ag aoject ct ty ag a

St d f COLaboratory TestsLaboratory Tests•• Miscibilities StudiesMiscibilities Studies•• PVT StudiesPVT Studies

Study of CO2Sources, Capture

and Transportation•• Extraction ExperimentsExtraction Experiments•• Core Flooding Core Flooding

ExperimentsExperiments

and Transportation

Simulation of L b Reservoir Laboratory

Experiments

Reservoir Simulations

Reservoir Data & Geological Data Economic

9LEMIGASLEMIGAS

Geological Data from Oil Field Analyses, Summary &

Conlcusions

Oil Fields SelectionOil Fields SelectionFOR COFOR CO22--EOREOR

o ViscosityReservoir Parameters EOR Methods

Nitrogen and Flue Gaso Gravityo Composition

Oil S t ti

HydrocarbonCO2Choose

th b to Oil Saturationo Formation Typeo Net Thickness

Immiscible gasMicellar/ASP/AlkalineP l

the best method

o Net Thicknesso Ave. Permeabilityo Depth

PolymerCombustionSteamo Depth

o TempSteamSurface Mining

10LEMIGAS

Oil Fields SelectionOil Fields Selection ( ’ )Oil Fields Selection Oil Fields Selection (cont’d)

Reservoir Parameter ScreeningCriteria

Oil Gravity API > 22 36 aViscosity Cp < 10 1.5Composition High percent of C5 toComposition High percent of C5 to

C12Oil Saturation %PV > 20 55Formation Type Sand St. or CarbonateNet Thickness ft Wide RangeAverage Permeability mD NCDepth ft > 2.500 aAverage Temperature oF NC

11LEMIGAS

Average Temperature oF NC

Oil Fields SelectionOil Fields Selection (cont’d)

INDONESIA PETROLEUM WORKING AREAS 2008INDONESIA PETROLEUM WORKING AREAS 2008

Oil Fields Selection Oil Fields Selection (cont d)

Sangata & Attaka

Kaji Semoga& Jene

J ti B & T B t12

LEMIGASLEMIGAS 33Total Working Areas = 200 Total Working Areas = 200 

Jati Barang & Tugu Barat

Oil Fields SelectionOil Fields Selection (cont’d)Oil Fields Selection Oil Fields Selection (cont d)

NO. COMPANY FIELD LOCATION

1 CHEVRON ATTAKA SOUTH KALIMANTAN1 CHEVRON ATTAKA SOUTH KALIMANTAN

2 PERTAMINA SANGATTA SOUTH KALIMANTAN

JATIBARANG WEST JAWA

TUGU BARAT WEST JAWA

3 MEDCO KAJI SEMOGA SOUTH SUMATERA3 CO J S OG SOU SU

JENE SOUTH SUMATERA

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Laboratory EvaluationLaboratory EvaluationLaboratory EvaluationLaboratory Evaluation

MMP DeterminationViscosity ReductionSwelling of OilSwelling of Oil Oil Composition Lighterp gRF Incremental Determination

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MMP DeteminationMMP DeteminationMMP DeteminationMMP Detemination

MMP Determination1.20

SLIM TUBE 0.80

1.00ct

ion)

0.60

ery

Fact

or (F

ra

MMP = 2150 psi

0.20

0.40

Rec

ove

1.2 PV OF CO2 INJECTED

BLOW DOWN

GAS BREAK THROUGH

15LEMIGAS

0.001000 1500 2000 2500 3000 3500 4000

Injection Pressure (Psi)

Increasing Ps and Swelling of OilSATURATION PRESSURE VS CO2 INJECTION

RELATIONSHIP2000

1200

1600

ure

(Psi

a)

400

800

1200

atur

atio

n Pr

essu

Initial Saturation Pressure

SWELLING OF OIL

1.60

0

400

0 10 20 30 40 50 60Mol Percent of CO2

Sa

0 80

1.00

1.20

1.40

t/Vin

itial

sat

)

Mol Percent of CO2

0.20

0.40

0.60

0.80Sw

ellin

g (V

sat

Initial Saturation Pressure

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0.000 500 1000 1500 2000

Saturation Pressure (Psia)

Viscosity ReductionViscosity ReductionViscosity ReductionViscosity ReductionVISKOSITAS MINYAK KAYA CO2Viscosity of CO2 Oil Rich

0.8

0.9Minyak Aw al Ps=835

Minyak Kaya CO2 Ps=1250

Minyak Kaya CO2 Ps=1380

al Ps=835

a CO2 Ps=1250

a CO2 Ps=1380

0.6

0.7

p)

Minyak Kaya CO2 Ps=1500

Minyak Kaya CO2 Ps=1658

Minyak Kaya CO2 Ps=1850

Cp

a CO2 Ps=1500

a CO2 Ps=1658

a CO2 Ps=1850

0.4

0.5

Vis

kosi

tas

(cp

Visc

osity

C

0.2

0.3V

0

0.1

0 1000 2000 3000 4000 5000 6000

17LEMIGAS

Tekanan (Psig)Pressure Psig

Oil Composition LighterOil Composition LighterOil Composition LighterOil Composition Lighter

Components Original

Reservoir Oil Mol %

CO2-Oil System I

Mol %

CO2-Oil System II

Mol %

CO2-Oil System III

Mol %

CO2-Oil System IV

Mol %

CO2-Oil SystemnV

Mol % Carbon Dioxide 0 770 26 558 33 687 39 778 47 494 55 958Dioxide 0.770 26.558 33.687 39.778 47.494 55.958

Nitrogen 0.010 0.007 0.007 0.006 0.005 0.004

Methane 17.260 12.774 11.534 10.475 9.133 7.661

Ethane 3 300 2 442 2 205 2 003 1 746 1 465Ethane 3.300 2.442 2.205 2.003 1.746 1.465

Propane 4.820 3.567 3.221 2.925 2.550 2.139

i-Butane 1.960 1.451 1.310 1.190 1.037 0.870

B t 2 770 2 050 1 851 1 681 1 466 1 229n-Butane 2.770 2.050 1.851 1.681 1.466 1.229

i-Pentane 2.010 1.488 1.343 1.220 1.064 0.892

n-Pentane 1.540 1.140 1.029 0.935 0.815 0.684

H 2 760 2 043 1 844 1 675 1 460 1 225Hexane 2.760 2.043 1.844 1.675 1.460 1.225

Heptane+ 62.800 46.479 41.968 38.113 33.230 27.873

100.000 100.000 100.000 100.000 100.000 100.000

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RF Incremental DeterminationRF Incremental DeterminationRF Incremental DeterminationRF Incremental DeterminationCore Holder

RECOVERY FACTOR OF COREFLOOD TESTAT INJECTION PRESSURE OF 2250 PSIG

80.0

90.0

100.0

OIP

) 1.0.E+04

1.0.E+05

(cc) Core flooding Rig

40 0

50.0

60.0

70.0

y Fa

ctor

(% O

O

1 0 E 02

1.0.E+03

as P

rodu

ctio

n (

G B kth h

10 0

20.0

30.0

40.0

Reco

very

1.0.E+01

1.0.E+02

Cum

m. G

aCumm. Oil Production

Cumm Gas Production

Waterflood

Gas Breakthrough

Initial Gasflood

19LEMIGAS

0.0

10.0

0 5 10 15 20 25 30 35

Injection (PV)

1.0.E+00

Cumm. Gas Production

Field Selection for Simulation Field Selection for Simulation StudyStudy

MMP COREFLOODPSIG RF (% Sor)FIELD WELL LOCATION

ATTAKA B-19 2150 90.00 EAST KALIMANTANUB-1 3150 No. CF

SANGATTA ST-77 2800 93.26 EAST KALIMANTANJATIBARANG JTB 137 2575 96 37 WEST JAWAJATIBARANG JTB-137 2575 96.37 WEST JAWATUGU BARAT TGB-06 3000 52.67KAJI SEMOGA KS-100 2420 70.00 SOUTH SUMATERAJENE Jene-12 3200 91 33JENE Jene-12 3200 91.33

Sangatta : LEMIGASJene : LEMIGASJati Barang : PERTAMINA

Selected For Simulation Study

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g

Simulation ProcessSimulation ProcessSELECT WELL DATA

VARIOGRAM ANALYSIS

ROCK CORE

GEOLOGICAL2

4

6

PETROPHYSICS

GEOLOGICAL-RESERVOIR MODELEXTRACT MARKER DATA

00.0 0.2 0.4 0.6 0.8 1.0

SB15

4300

4400

4500

SURFACE STRUCTUREUPSCALING

RESERVOIR SIMULATION

3D SEISMIC

4600

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Sangata Field SimulationSangata Field SimulationggSangatta

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Sangata Field SimulationSangata Field SimulationSangata Field SimulationSangata Field Simulation

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Jene Field SimulationJene Field SimulationJene Field SimulationJene Field Simulation

Jene and Singa

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Jene Field SimulationJene Field SimulationJene Field SimulationJene Field Simulation

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COCO StorageStorage EOR PotentialEOR PotentialCOCO22 Storage Storage –– EOR PotentialEOR Potential

Rule-of-Thumb Approach (historical experience)

Incremental Oil Recovery (% OOIP)Incremental Oil Recovery (% OOIP)• 8-16 %

Gross CO2 Utilization (Mcf/Bbl)• 5-10 Mcf/Bbl

Net/Gross Utilization Ratio (fraction)0 5• 0.5

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Plan of ImplementationPlan of Implementation (cont’d)Plan of Implementation Plan of Implementation (cont d)

Preparation of Implementation

◆ Estimating Enhanced Oil Productionby Laboratory Tests & Studiesby Laboratory Tests & Studies

◆ Estimating CO Delivery Cost◆ Estimating CO2 Delivery Cost

◆ Studying Total Project Economics◆ Studying Total Project Economics

◆ Studying the Merit of CDM Scheme27

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◆ Studying the Merit of CDM Scheme

C t f

Plan of Implementation Plan of Implementation (cont’d)Concept of

CO2 Emission Reduction and Utilization In Bontang Area

4,300 T/DCO2 Compression&Existing

CO2 (Off Gas)

&Dehydration

gFacilities

9,500 T/D2,000 psig

CO2 Compression&

Dehydration

NeighborOil Fields

CO2 (Off Gas)

CO2 PipelineOil

ProductionIncremental

Flue Gas

Dehydration ATTAKAHANDILBEKAPAI

SANGATTAEtc.

CO2 Pipeline(8~20”)

16 000 T/D

Incremental

CO2

Flue Gas

BontangLNG Plant

CO2 RecoveryCO2 Compression

&Dehydration

16,000 T/D

28LEMIGAS

ConclusionsConclusions

• CO2 emission especially from Petroleum Industries must be re-injected to follow CDM Scheme

• EOR is the only method to increase oil yrecovery and offset of cost only project for emission reduction

• Indonesia may build up work cooperation with other countries to implement CO2-with other countries to implement CO2EOR project at Indonesian oil field

29LEMIGAS

THANK YOUTHANK YOUTHANK YOUTHANK YOU

30LEMIGAS