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Modeling and mapping the area of potential impact (AoPI) for Class VI CO2 injection wells
Stephen Kraemer, Ph.D.Research Hydrologist
U.S. Environmental Protection AgencyOffice of Research and Development
y g
Office of Research and DevelopmentAthens, Georgia
Ground Water Protection Council Annual Forum,Atlanta, Georgia,
26 September, 2011
Office of Research and Development, National Exposure Research LabEcosystems Research Division, Athens, Georgia
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Disclaimer• This material has been reviewed for presentation, and does not
represent the policy of the US Environmental Protection Agency.• Mention of commercial products does not indicate endorsement by
the Agency.
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How to cut At leasttriplingt CO
Strategy for Reducing Emissions
CO2 emissions?
atm CO2
Emissions
one wedge (1GtC/yr):
emissions?
carbon capture and storage (CCS): geologic sequestration (GS)
Avoiddoubling
introduce systems to capture CO2 and store it underground at 800
Stabilizeunderground at 800 large coal-fired plants or 1,600 natural-gas-fired plants
atm 500 ppm
3
plants.
Pacala, Socolow, Science, 2004
Today 20571957
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CO2 Stationary Sources
electricity generationcoal and natural gas
4
NETL 2010 Atlas
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Advantages and challenges ofdeep storage of CO2p g 2
Benson, Cook, IPCC
NETL, 2010
5
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Deep Saline Formations
Illinois BasinMt. Simon Sandstone
6NETL 2010 Atlas
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Potential threats to underground sources of drinking water
7
Birkholzer et al., 2009
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EPA UIC Area of Review (AoR)computational/numerical modeling and mapping
Guidance forGuidance for
CO2front
permit applicantpermit applicant
front
Critical pressure frontfront
AoR = MESPOP (maximum extent of the separate-phase plume
8
p p por the pressure front)
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Area of Potential Impact (AoPI)semi-analytical modeling and mapping
pressure influenceBlock-diagram
view Guidance forGuidance forpermit reviewerpermit reviewer
threshold pressure
CO2 plume
Plan view
Primary seal and secondary traps and seals
from Birkholzer et al., 2008
USDW (TDS<10,000 mg/L
y y p
injection well freshunpluggedwell
99Cross-sectional view
Storage Unit brineCO2
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Single Layer Concept Multi Layer Conceptet
al.
09
yes aquitard storage
boun
dary
Zhou
20
0
en o
r clo
sed
bop
eeb based frame ork
CAMELOT solver
web-based framework
desktop framework
TTim solver
desktop framework
GeoSequestrationBAEM
10
GeoSequestration
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Maximum extent CO2 front
Qvertically integrated approach
Q
σc, cCO2
Haσb, b
ka, a
brine
r11
r
(Nordbotten and Celia, JFM, 2006)
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Pressure Influence (single aquifer)
S
uWKHQp );(
42
p is the change in pressure [FL-2]
KHtrS
u4
2
Q is the injection rate (positive into the aquifer) [L3T-1]
K is the hydraulic conductivity of the aquifer [L2]
S is the storativity of the aquifer [-]
Qr is the radial distance from the center of the injection well [L]
H is the aquifer thickness [L]
t is time since injection started [T]
HK S
t is time since injection started [T]
W() is the well function
Note: an equivalentK, S Note: an equivalent injection volume rate of brine is computed by dividing CO2 mass rate of i j ti b CO d it @
1212r
(Theis, 1935)injection by CO2 density @ pressure, temperature. (Altunin, 1975).
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Pressure influence … continued
yes aquitard storage
-Jac
ob55
no aquitard storage
Moe
nch
1985
yes aquitard storage
Han
tush
-19
5 M
. yes aquitard storage n
hou
et a
l20
09
y q g
dary
con
ditio
n
1313
Z
boun
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Case StudyIllinois Basin
1E+06 800750700650600
Iowa
WisconsinWisconsin Arch
Kankakee Arch C
ppi R
iver A
rch
GroundwaterResourcesRegion
Thickness Mt. Simon (m)
Illinois Basin800000
900000 550500450400350300250200
Illinois
CincinnatiA
rch
ADM Site
Miss
issip
p
20 hypothetical injection wells5 Mt CO2/yr each
600000
700000
200150100500
IndianaCore Injection Area
Ozark
Dom
e
5 Mt CO2/yr eachTotal 100 Mt/yr
800000 900000 1E+06 1.1E+06 1.2E+06 1.3E+06
500000KentuckyMissouri
e
Pascola Arch
2000
mBirkholzer, Zhou, IJGCC 2009Zhou et al., GW, 2010
141414
Mt. Simon SandstoneEau Clare sealTOUGH2/ECO2N
24 node Linux supercomputer
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Pressure fronts --- basin scale,CO2 fronts --- local scale
0.1
0 5
40353020
CO2 saturation at 50 yrspressure, bars50 yrs
0.5
1
5
1
2010510.50.1
10
2030
35
20
105
1
151515800000
1E+061.2E+06
600000
800
Birkholzer, Zhou, 2009Zhou et al., 2010
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Pressure influence, Mt. Simon fm, 50 yrs, semi-analytical, single
phase solution, single layer
0.1
0.5
1
40353020105 phase solution, single layer
5
10
2030
35
20
10.50.1
“AoPI” ¯10
5
1
“AoR”G Sit L ti
¯
G
G Site LocationPressure increase
0.1 bar0.2 bar G
0.5 bar1.0 bar2.0 bar5 0 bar5.0 bar10.0 bar20.0 bar50.0 bar
1616
StatesIllinois BasinCounties 0 50 100 150 20025
Kilometers
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Maximum extent threshold pressure
fresh zdw
w
l
ti tc
salinebi
Hbc
Bandilla, Kraemer, Birkholzer, under reviewstatic calculations- assume equilibrium density
17
assume equilibrium density- assume uniform density
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0.12dynamic vs static threshold pressure
kg/s
)
0.1
DP = 1 barDP = 2 barDP 3 b
quife
r(k 0.08
DP = 3 barDP = 5 barDP = 10 barDP = 15 bar
ate
into
A 0.06
ce(m
)
600
-400
-200 Shale
Aquifer
Flow
Ra
0.04D
epth
Bel
owS
urfa
c
0 500 1000 1500 2000
-1400
-1200
-1000
-800
-600
Reservoir
Pressure BuildupBoundary Condition
Wellbore
TOUGH2
0.02 static threshold pressureequilibrium density = 2.1 baruniform density=1.3 bar
Radius (m)0 500 1000 1500 2000
1818Time (days)
10-1 100 101 102 103 104 1050
Birkholzer et al, 2011
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19Mark Bakker
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20Mark Bakker
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7
21Mark Bakker
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7
6
22Mark Bakker
65 4
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GeoSequestration v0.2web interface- web interface
Jay Rineer team
24
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BAEM v0.1 – desktop interfaceBASINS Analytic Element ModelBASINS Analytic Element Model
Jay Rineer team
CAMELOT l iCAMELOT plug-in
25TTim plug-in Matt Tonkin team
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Single Layer Concept Multi Layer ConceptAoPIT l f
ou e
t al.
2009
yes aquitard storage
ed b
ound
ary Tools for
Regulators
Zho 2
open
or c
lose
pressure influence
CAMELOT solver
TTim sol er
threshold pressure
CO l
b b d f k
TTim solverCO2 plume
web-based frameworkdesktop framework
BAEM26
GeoSequestration
BAEM