preliminary tough2 model of king island co2 injection · 2018-01-12 · west coast regional carbon...
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West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.1
Preliminary TOUGH2 Model of King Island CO2 Injection
Christine Doughty
Presented by Curt Oldenburg
Earth Sciences DivisionLawrence Berkeley National Laboratory
October 25, 2011
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Modeling Approach
• Characterization study—no injection
• But injection can be simulated
• Properties obtained from nearby wells, core, well logging, and surface seismic can be used to define the model system
• Simulation of injection at Phase III scale or industrial scale can be carried out to understand local site and regional performance
• Two examples from other regions, one at each scale
• Preliminary King Island simulation results
West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.2
Denbury CO2-EOR at Cranfield, Mississippi
GCS Pilot-Test Simulation (Chris Doughty (LBNL))
Model Results
Model Development
•Injection-well log shows two high-permeability layers separated by a shale baffle
•Layered model, finer at wells
•CO2 injected over interval shown by black bar
SECARB Phase III CO2 Injection
•Injecting 200-500 T/day CO2 since December 2009 into water leg on flank of dome
•Initial Condition: brine saturated with CH4
•Two monitoring wells with U-Tubes to collect samples, mass spec for gas composition
•Multiple tracer pulses released
•Time-lapse well logging for saturation profiles
•Seismic and electrical resistivity imaging
Key Features in Breakthrough Curves
•Pulse of gas-phase CH4 forms at leading edge of plume as CO2 preferentially dissolves
•Multiple CH4 peaks illustrate distinct flow paths above and below shale baffle
•Low, wide peaks for later tracer releases -evidence of self-sharpening plume front
Simulations of a Full Deployment CO2 Storage Scenario in the Illinois Basin (Zhou and Birkholzer (LBNL))
• Concern has been raised that CO2 storage causes unacceptable pressure rise (e.g., Ehlig-Economides and Economides, J. Petrol. Tech., 2010).
302520151051
Pressure Buildup (bar) at 50 years
Pressure rise (bar) at end of injection
• Simulated pressure rise is approx. 30 bars centered in the injection area. This pressure dissipates with time as brine flows into low-permeability cap rock over large areas.
• CO2 plumes from each of the 20 injection sites do not intermingle as 3D effects (vertical flows) allow efficient filling of pore space (Zhou and Birkholzer, GHGS&T, 2011).
CO2 saturation after 200 years
0.60.50.40.30.20.10
CO2 Saturation at 200 years
190 km
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0k
m
Vertical cross-section of CO2
saturation after 200 years for one site.
704 706 708 710-2400
-2200
-2000
-1800
0.60.50.40.30.20.1
200 years
m
km
-300-700-1100-1500-1900-2300-2700-3100-3500-3900-4300
800 900 1000 1100 1200 1300
500
600
700
800
900
1000
IllinoisBasin
Wisconsin
Indiana
Iowa
MissouriKentucky
Illinois
Cin
cinn
atiA
rch
Kankakee Arch
Mis
siss
ipp
i Riv
erA
rch
Wisconsin Arch
Ozark Dome
Pascola Arch
ADM Site
Core Injection Area
Km
Km
GroundwaterResource Region
-4300 m
-500 m
m
• We have simulated the injection of 5 Gt CO2 over 50 years at 20 sites (5 Mt/yr at each site) in the Mt. Simon Formation.
Elev. of the top of the Mt. Simon Fm.
West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.3
King Island Location Map
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Preliminary Model Development
• Vertical Layering
• Structure
• Lateral Extent and Boundary Conditions
• Material Properties
• Initial Conditions
• Grid and Representation of well
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West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.4
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Citizen Green WellFormation Tops and
Core Intervals
Four target sands:
Domengine
Mokelumne River
Top Starkey
Starkey/Peterson #1
Nortonville shale
Domengine sand
Capay shale
Mokelumne River sand
H&T shaleTop Starkey sand
shale & sand (Starkey)
shale (Starkey)
Peterson #1 sand
Peterson #2 sand
shale (Starkey)
Core intervals
King Island 1-28 well
Citizen Green well
Top of shale
Top of sandstone
Core interval
• Ignore gorges
• Approximate dip as uniform dip: 1.6o up to ENE
From Downey and Clinkenbeard, 20118
West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.5
ConstantPressure
Closed
Closed
Closed
• Axis aligned with dip direction
• West and south boundaries approximately aligned with faults
• East boundary open as Mokelumne may abut another permeable formation
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Material Properties• Rough estimates and literature values• Sands
– Porosity 0.25-0.35– Permeability 50 – 500 md– Anisotropic: kv/kh 0.01 to 0.1
• Shales– Porosity 0.10– Permeability 10 d– Anisotropic: kv/kh 0.1
• Properties are effective values that account for sub-grid-scale heterogeneity
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West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.6
Initial Conditions
• Single-phase liquid brine (salinity 0.05, or 50,000 ppm)
• Hydrostatic pressure profile
• Geothermal temperature gradient
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Grid and Representation of Well
• Rectangular grid– 24 layers– 31 by 30 grid blocks per layer, 100 m resolution at
well• Diagonal well represented by “stair-steps” in
rectangular grid• Injection partitioned among grid block
representing well according to permeability-thickness product– Does not account for different pressure gradients
in well (CO2) and formation (brine)– Over-estimates injection at greater depth
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West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.7
Simulation of CO2 Injection
• TOUGH2 numerical simulator• Fully coupled multiphase fluid flow• Isothermal simulations• CO2 exists as a supercritical phase and
dissolves in brine• Two cases
– 1 MT over 4 years (phase 3 size)– 10 MT over 4 years (better problem for
coarse grid)
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CO2 injection at 250,000 T/yr (t = 4 years)
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West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.8
CO2 injection at 2,500,000 T/yr (t = 4 years)
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Future work
• Incorporate actual geology
• Refine grid
• Simulate different injection depths
• Simulate post-injection period to study trapping
• Incorporate sub-grid-scale heterogeneity
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West Coast Regional Carbon Sequestration PartnershipAnnual Business Meeting
Lodi, CAOctober 24-26, 2011
Oldenburg p.9
CO2 Inventory Evolution
Doughty, C.A., Trans. Porous Med., 82, 49-76, 2010.
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Acknowledgments
This work was supported by the Assistant Secretary for Fossil Energy (DOE), Office of Coal and Power Systems, through the
National Energy Technology Laboratory (NETL), U.S. Department of Energy, and by Lawrence Berkeley National Laboratory under
Department of Energy Contract No. DE-AC02-05CH11231 .
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