Reservoir Simulation Modeling of the Yubari CO -ECBM ... SP02230… · • History-Matching ... Genetically Optimized History Matching (GenOHM) Procedure Workflow ... Final History

Prepared by:Scott R. Reeves

Advanced Resources International, Inc.Houston, TX

February 23, 2007Tokyo, Japan

Reservoir Simulation Modeling of the Yubari CO2-ECBM/Sequestration Pilot, Ishikari Basin, Japan

2

JCOAL Yubari SP022307

Presentation Outline

•• Pilot DescriptionPilot Description•• Model DevelopmentModel Development•• HistoryHistory--MatchingMatching•• Conclusions/RecommendationsConclusions/Recommendations

3


Location/Geology

●YUBARI●YUBARI

FaultsFaults

Test Site

4


Summary of Reservoir Data Provided

Parameter Value RemarksDepth: 890 m @ IW1Thickness: 5.66 mFormation Dip: 25 degreesInitial Average Reservoir Pressure 10.2 MPa @ IW1Reservoir Temperature: 29.5 oCCleat Interval 7.5 mmInitial Water Saturation: 100%Initial Absolute Permeability: 1 mdRelative Permability LinearGas Content (in-situ) 22.2 cm3/g oversaturatedDry, Ash-Free Langmuir Volume CH4 28 ml/grDry, Ash-Free Langmuir Volume CO2 44 ml/grDry, Ash-Free Langmuir Volume N2 9.3 ml/grAsh& Moisture Content 8.4%In-Situ Coal Density 1.34 g/ccLangmuir Pressure CH4 1.785 MPaLangmuir Pressure CO2 0.972 MPaLangmuir Pressure Ｎ2 6.825 MPaSorption Time Constant CH4 5.0 daysSorption Time Constant CO2 2.5 daysInitial Free Gas Composition 97.4% CH4; 2.0% CO2; 0.6% N2

5


Illustration of Isotherms

0.00

5.00

10.00

15.00

20.00

25.00

30.00

35.00

40.00

45.00

- 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000

Pressure, kPa

Gas

Con

tent

, m3/

tonn

e

MethaneCarbon DioxideNitrogen

6


Simulation Model Description

67m

N

25˚ dip

20 x 27 x 3 (1,620 gridblocks)

7


Injection/Production/Pressure History

Bot

tom

hole

Pre

ssur

ePr

oduc

tion/

Inje

ctio

n

Production Well Injection WellINJECTION BHP

0

2000

4000

6000

8000

10000

12000

14000

16000

18000

0 100 200 300 400 500 600 700 800

Time (Days)

BH

P kP

a

PRODUCTION BHP

0

1000

2000

3000

4000

5000

6000

7000

8000

9000

0 100 200 300 400 500 600 700 800Time (days)

BH

P (K

pa)

Injecting Well Production/Injection History

0

500

1000

1500

2000

2500

3000

3500

4000

0 100 200 300 400 500 600 700 800Time (Days)

Rat

e, m

3/d

Water Production (converted injector)CO2 Injection RateGas Production rateN2 Injection Rate

GAS AND WATER PRODUCTION RATES

0

100

200

300

400

500

600

700

800

0 100 200 300 400 500 600 700 800

Time (Days)

Gas

pro

duct

ion

Rat

e (m

3/d)

0

1

2

3

4

5

6

7

8

9

Wat

er p

rodu

ctio

n ra

te (m

3/d)

8


Well Control and Match Parameters

IW-1PW-1

Bottomhole Pressure (1000)Bottomhole Pressure (1.0)

Water Production Rate (0.1)Water Production Rate (1.0)Match Parameters(weight factors)

Gas Production Rate (1000)Gas Injection Rate (1.0)

Gas Production Rate (1000)

Gas Production/Injection RateGas Production RateWell Control

9


Genetically Optimized History Matching (GenOHM) ProcedureWorkflow

Error Function Calculation

Case Definition • Reservoir characterization • Model construction • Ranges selected for uncertain

parameters

ClearVu1 variable selections generated.

COMET32 input file created.

COMET3 run.

Error functions computed.

Acceptable Match?

Finish

# in

tera

tions

/bat

ch

1 NuTech Solutions 2 Advanced Resources International

No

Yes

10


Fixed Model InputsParameter Value Units Source

Depth 890 m YubariThickness 5.4 m YubariDip 25 Degrees YubariInitial Pressure 10.3 MPa YubariReservoir Temperature 29.5 °C Yubari

Dry, Ash-Free Langmuir Volume CH4 28 ml/g YubariDry, Ash-Free Langmuir Volume CO2 44 ml/g YubariDry, Ash-Free Langmuir Volume N2 9.25 ml/g YubariLangmuir Pressure CH4 1.785 MPa YubariLangmuir Pressure CO2 0.972 MPa YubariLangmuir Pressure Ｎ2 6.825 MPa YubariSorption Time Constant CH4 5.00 Days YubariSorption Time Constant CO2 2.50 Days YubariSorption Time Constant N2 7.50 Days assumedAsh& Moisture Content 8.37 % YubariDensity 1.34 g/cc Yubari

Permeability Exponent 3 - assumed

Krw max 1 - assumedSgr 0 - assumed

Formation Properties

Sorption Properties

Relative Permeability Relationships

Permeability Relationships

11


History Match VariablesParameter Value Units Source Min Max

Formation PropertiesPorosity - % - 0.500 3.00Initial Water Saturation 1 - Yubari 0.9 1Absolute Permeability 1.0 mD Yubari 1 5Permeability Anisotropy - - - 1 10Permeability Z-factor - - - 0.001 1Pore Compressibility - 1/kPa - 1.00E-05 1.00E-03Matrix Compressibility - 1/kPa - 1.00E-07 1.00E-05Differential Swelling Factor, CO2 - - - 1 3Differential Swelling Factor, N2 - - - 0.5 1.0Relative Permeability RelationshipsSwir - - - 0.1 0.25Krg max - - - 0.6 0.9Expw - - - 1 3Expg - - - 1 3Well ParametersSkin Producer/Injector - - - 0 20

* 14 variables

12


Permeability Models

Relative Permeability Model

Permeability Model

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00

Water Saturation, fraction

Rel

ativ

e Pe

rmea

bilit

y, fr

actio

n

Krw

Krg

Sw - Swr Krwexp

1-Swr-Sgr

1-Sw-Sgr Krgexp

1-Swr-Sgr

Krw = Krwmax

Krg = Krgmax

Krgmax

Krgexp

Swr

Krwexp

Krwmax

Sgr

0

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

1.8

2

0 2000 4000 6000 8000 10000 12000 14000 16000

Pressure, kPa

Perm

eabi

lity,

mD

CH4 CO2 N2

∅ n

∅i

k = ki

∅ = ∅i 1 + Cp (P-Pi) - (1 - ∅) Cm dPi [ C CH4 + CkCO2 CCO2 + CkN2 CN2 - Ci ]

dCi

13


Variable Convergence*

* Not from final history-match case

Permeability Anisotropy Convergence

0

1

2

3

4

5

6

7

8

9

0 50 100 150 200 250 300 350 400 450 500

Number of Runs

Perm

eabi

lity

Ani

sotr

opy

Valu

e

Differential Swelling Factor, N2

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

0 50 100 150 200 250 300 350 400 450 500

Number of Runs

Diff

eren

tial S

wel

ling

Fact

or V

alue

Irreducible Water Saturation Convergence

0

0.05

0.1

0.15

0.2

0.25

0.3

0 50 100 150 200 250 300 350 400 450 500

Number of Runs

Irred

ucib

le W

ater

Sat

urat

ion

valu

e

Differential Swelling Factor, CO2

0

0.5

1

1.5

2

2.5

0 50 100 150 200 250 300 350 400 450 500

Number of Runs

Diff

eren

tial S

wel

ling

Fact

or V

alue

14


Error Function Reduction*PRODUCER: BOTTOMHOLE PRESSURE ERROR FUNCTION

1

10

0 50 100 150 200 250 300 350 400 450 500Number of Runs

Erro

r Fun

ctio

n Va

lue

.

TOTAL ERROR FUNCTION

1

10

100

1000

10000

100000

0 50 100 150 200 250 300 350 400 450 500Number of Runs

Erro

r Fun

ctio

n Va

lue

PRODUCER: WATER PRODUCTION RATE ERROR FUNCTION

0.1

1

0 50 100 150 200 250 300 350 400 450 500Number of Runs

Erro

r Fun

ctio

n Va

lue

.

* Not from final history-match case

INJECTOR: BOTTOMHOLE PRESSURE ERROR FUNCTION

0.1

1

10

100

0 50 100 150 200 250 300 350 400 450 500Number of Runs

Erro

r FU

nctio

n Va

lue

15


Final Match: PW-1

BOTTOMHOLE PRESSURE

0

2000

4000

6000

8000

10000

12000

0 100 200 300 400 500 600 700 800Simulation Days .

Pres

sure

, kPa

.

ActualSimulated

GAS PRODUCTION RATE

-100

0

100

200

300

400

500

600

700

800

0 100 200 300 400 500 600 700 800

Simulation Days .

Rat

e, m

3/d

.

ActualSimulated

WATER PRODUCTION RATE

0

1

2

3

4

5

6

7

8

9

0 100 200 300 400 500 600 700 800Simulation Days .

Rat

e, m

3/d

.

ActualSimulated

16


Final Match: IW-1

CO2 INJECTION RATE

0

500

1000

1500

2000

2500

3000

3500

4000

0 100 200 300 400 500 600 700 800Simulated Days

Gas

Inje

ctio

n R

ate,

m3/

d

Actual

Simulated

BOTTOMHOLE PRESSURE

0

10000

20000

30000

40000

50000

60000

70000

80000

0 100 200 300 400 500 600 700 800Simulated Days .

Bot

tom

-Hol

e Pr

essu

re (K

Pa)

.

Actual DataSimulated Data

Gas and Water Production Rates

0.000

20.000

40.000

60.000

80.000

100.000

120.000

140.000

0 100 200 300 400 500 600 700 800

Time (Days)

Gas

Rat

e, m

3/d

0.000

0.500

1.000

1.500

2.000

2.500

3.000

Wat

er R

ate,

m3/

d

Gas Production Rate Actual Water Production Rate Simulated Water Production Rate

N2 INJECTION RATE

0

500

1000

1500

2000

2500

3000

3500

4000

0 100 200 300 400 500 600 700 800Simulated Days

N2

inje

ctio

n ra

te, m

3/d

Actual DataSimulated Data

17


Illustration of Gas-Movement

0

100

200

300

400

500

600

700

0 100 200 300 400 500 600 700 800Simulation Days .

Rat

e, m

3/d

.

0

20

40

60

80

100

120CH4N2CO2

Detailed Gas Production

0

100

200

300

400

500

600

700

640 645 650 655 660 665 670 675 680

Time (Days)

CH

4 G

as P

rodu

ctio

n R

ate,

m3/

d

0

20

40

60

80

100

120

N2

and

CO

2 Pr

oduc

tion

Rat

e, m

3/d

ch4 n2 co2

Note: N2 observed at producer well (in field) one day after injection ceased, or 10 days after injection began.

18


Final History Match VariablesParameter Value Units Source Min Max Optimized

Formation PropertiesPorosity - % - 0.500 3.00 2.17Initial Water Saturation 1 - Yubari 0.9 1 0.95Absolute Permeability 1.0 mD Yubari 1 5 2.02Permeability Anisotropy - - - 1 10 8.55Permeability Z-factor - - - 0.001 1 0.087Pore Compressibility - 1/kPa - 1.00E-05 1.00E-03 2.86E-04Matrix Compressibility - 1/kPa - 1.00E-07 1.00E-05 6.39E-07Differential Swelling Factor, CO2 - - - 1 3 1.65Differential Swelling Factor, N2 - - - 0.5 1.0 0.84Relative Permeability RelationshipsSwir - - - 0.1 0.25 0.15Krg max - - - 0.6 0.9 0.62Expw - - - 1 3 1.28Expg - - - 1 3 1.6Well ParametersSkin Producer/Injector - - - 0 20 8.9

19


History-Match Permeability Models

Absolute PermeabilityAbsolute Permeability Relative PermeabilityRelative Permeability

0

1

2

3

4

5

6

0 2000 4000 6000 8000 10000 12000 14000 16000

Pressure, kPa .

Perm

eabi

lity,

mD

CH4 CO2 N2

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00

Water Saturation, fractionR

elat

ive

Per

mea

bilit

y, fr

actio

n

Krw

Krg

20


Effect of N2 Injection on Permeability

Permeability distribution on last day of N2 injection.

21


Conclusions

•• Representative model of Representative model of YubariYubari reservoir reservoir conditions constructed; successful historyconditions constructed; successful history--match of match of ECBM performance achieved.ECBM performance achieved.

•• Results indicate:Results indicate:–– ~2 ~2 mdmd permeabilitypermeability–– ~2% porosity~2% porosity–– ~0.95 initial water saturation~0.95 initial water saturation–– ~9:1 permeability anisotropy~9:1 permeability anisotropy–– ~+9 skin damage~+9 skin damage

•• NN22 –– injection appears to improve permeability and injection appears to improve permeability and injectivityinjectivity..


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Documents

Reservoir Simulation Modeling of the Yubari CO -ECBM ... SP02230… · • History-Matching ... Genetically Optimized History Matching (GenOHM) Procedure Workflow ... Final History