preliminary tough2 model of king island co2 injection · 2018-01-12 · west coast regional carbon...

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

2

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



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

14

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.



Oldenburg p.3

King Island Location Map

5

Preliminary Model Development

• Vertical Layering

• Structure

• Lateral Extent and Boundary Conditions

• Material Properties

• Initial Conditions

• Grid and Representation of well

6



Oldenburg p.4

7

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



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

9

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

10



Oldenburg p.6

Initial Conditions

• Single-phase liquid brine (salinity 0.05, or 50,000 ppm)

• Hydrostatic pressure profile

• Geothermal temperature gradient

11

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

12



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)

13

CO2 injection at 250,000 T/yr (t = 4 years)

14



Oldenburg p.8

CO2 injection at 2,500,000 T/yr (t = 4 years)

15

Future work

• Incorporate actual geology

• Refine grid

• Simulate different injection depths

• Simulate post-injection period to study trapping

• Incorporate sub-grid-scale heterogeneity

16



Oldenburg p.9

CO2 Inventory Evolution

Doughty, C.A., Trans. Porous Med., 82, 49-76, 2010.

17

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 .

18

preliminary tough2 model of king island co2 injection · 2018-01-12 · west coast regional carbon...

Documents