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Pre-Injection Reservoir Modeling and Uncertainty Study for Illinois Basin-Decatur Project Ozgur Senel (Schlumberger Carbon Services) Nikita Chugunov (Schlumberger - Doll Research)
© 2011 Schlumberger. All rights reserved. An asterisk is used throughout this presentation to denote a mark of Schlumberger. Other company, product, and service names are the properties of their respective owners.
Outline
● Introduction
● Reservoir Model Workflow ― Upscaling ― Reservoir Model Calibration ― Base Case
● Uncertainty Analysis ― Wellbore Pressures and CO2 Mass Partitioning ― Reservoir Scale: Plume and Pressure Pulse Extent ― Verification Well: Westbay* multilevel groundwater characterization
and monitoring system responses
Introduction
2800 ft
STRAT COLUMN OF THE ILLINOIS BASIN
2800 ft
Injector
Verification
Workflow
Seismic Data
Seismic Data Attribute Analysis
Petrophysics
Geological Model
Facies Model
Porosity Model
Permeability Model
Upscaling
Predictive Reservoir Simulations
Uncertainty Analysis
Upscaling
Geological Model:
● 1298 × 1308 × 534 ~ 906M Cells
● 150 × 150 ft cells
Reservoir Model:
● 20 × 20 mile
● 143 × 143 ×148 ~ 3M Cells
● 50ft to 1500ft lateral cells
Static Model Upscaled Model
Eau Claire
Mount Simon
Water Injection/Fall Off Test Reservoir Model Calibration
Reservoir Model calibrated on skin and global permeability
multiplier.
Time, days
0 1 2 3 4 5
Pres
sure
, psi
3000
32
00
3400
36
00
3800
40
00
4200
44
00
4600
Base Case - Simulation Results
Injection Rate & Pressure Profiles
Injection Ramp-Up Time
7 Days
Time, years
0 1 2 3 4 5
Pres
sure
, psi
C
O2 Flow
Rate, M
t/d
Injection Pressure & Rate Profile 80
0 12
00
1600
20
00
2400
28
00
3200
36
00
4000
Wellhead Pressure
Bottomhole Pressure
Injection Rate
Fracturing Pressure ~ 5025 psig at 7025 ft
0 500
1000
CO2 Mass Partitioning
0
10
20
30
40
50
60
70
80
90
100
0 10 20 30 40 50 60 70 80 90 100
Mas
s Fr
actio
n, %
Time, years
CO2 Mass Partitioning
Unbounded, %
Trapped, %
Dissolved, %
IBDP - CO2 Plume & Pressure Pulse Evolution
50 Years
Pressure - Saturation Plume Evolution
0
100
200
300
400
500
600
700
0 1 2 3 4
Rad
ius,
ft
Time, Years
Equivalent Radius of 184 psi Pulse
Pressure Pulse Radius
0
75
150
225
300
0 10 20 30 40 50 60 70 80 90 100
Are
a, a
cres
Time, Years
CO2 Plume Area
IBDP
Uncertainty Analysis
Input Parameters
Parameter Distribution-Range
Number of Realizations 128
Residual H2O Saturation (Swr) Uniform(0.15, 0.55)
Residual CO2 Saturation (Sgr) Uniform(0.05, 0.30)
CO2 Relative Permeability @ Swr Uniform(0.30, 0.70)
kv/kh Reservoir Unit Uniform(0.20, 0.70)
kv/kh Non-Reservoir Unit Uniform(0.01, 0.05)
Upper Perforation Skin Uniform(-0.7, 0)
Lower Perforation Skin Uniform(-0.7, -1.4)
Output Parameters
● Injection Ramp-Up Time
● Injector & Verification Well Bottomhole Pressures
● Injector Tubing Head Pressure
● CO2 Mass Partitioning
● CO2 Saturation Plume & Pressure Pulse Development
● Westbay – Saturation & Pressure Profiles
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
2nd Analysis
Time, Days
Injection Rate Ramp-Up Time
Cum
ulat
ive
Prob
abili
ty
CDF
Injection Ramp-Up Time
P10: 10 days P50: 22 days P90: 80 days
Best Case: 5 days
Worst Case: 307 days
1600
1700
1800
1900
0 1 2 3 4 5
Pres
sure
, psi
a
Time, years
Base
P10
P50
P90
3000
3200
3400
3600
3800
4000
0 1 2 3 4 5
Pres
sure
, psi
Time, Years
Base Case
P10
P50
P90
Pressure Profiles
Injector – Wellhead Pressure (120°F)
Injector – Bottomhole Pressure
Compression capacity is 2000psi
Verification – Bottomhole Pressure
Max injection bottomhole pressure is 80% of fracturing pressure
3200
3250
3300
3350
3400
0 1 2 3 4 5
Pres
sure
, psi
Time, years
Base Case
P10
P50
P90
1600
1700
1800
1900
0 1 2 3 4 5
Pres
sure
, psi
a
Time, years
Base
P10
P50
P90
1550
1350
1450
1250
Injector – Wellhead Pressure (90°F)
0
0.2
0.4
0.6
0.8
1
0 10 20 30 40 50
Mas
s, F
ract
ion
Time, Years
Trapped CO2
P10
P50
P90
Base
0
0.1
0.2
0.3
0.4
0.5
0.6
0 10 20 30 40 50
Mas
s, F
ract
ion
Time, Years
Dissolved CO2
P10
P50
P90
Base
CO2 Mass Partitioning
0
0.2
0.4
0.6
0.8
1
0 10 20 30 40 50
Mas
s, F
ract
ion
Time, Years
Unbounded CO2
P10
P50
P90
Base
Pressure Profile at Verification Well
Color-profile indicates the probability of ΔP at a given depth along verification well.
Pressure Profile at Verification Well
Color-profile indicates the probability of ΔP at a given depth along verification well.
CO2 Saturation Profile at Verification Well
Color-profile indicates the probability of CO2 saturation at a given depth along verification well.
Concluding Remarks
● Reservoir model consistent with all available data
● Injection rate ramp-up time (P10-P90): 10 - 80 days
● CO2 mass partitioning (P10-P90): ― 15 - 25% CO2 dissolved by 2062 ― 40 - 65% CO2 residually trapped by 2062
● Plume containment and Area of Review (AOR): ― No vertical migration above 6,350 ft ― Spatial extent (P10-P90): 134.5 - 254 Acres by 2062 (N-NW) ― AOR (P10-P90): 450 - 630 ft radius during injection (ΔP = 184psi)
● Verification well: probability estimates for Westbay responses
CO2 Injection in a Saline Formation: Pre-Injection Reservoir Modeling and Uncertainty Study for Illinois Basin-Decatur Project
Ozgur Senel (Schlumberger Carbon Services)
Nikita Chugunov (Schlumberger - Doll Research)
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