Assessment of Geological Carbon Sequestration in the Illinois Basin CO 2 Injection into Illinois Coals David G. Morse 1 and John A. Rupp 2 1 Illinois State Geological Survey 2 Indiana Geological Survey Coal-Seq IV Forum Denver, Colorado November 9-10, 9 2005
Co-workers: Acknowledgements Ilham Demir- ISGS Scott Elrick- ISGS Christopher Korose- ISGS Maria Mastalerz- Indiana Geological Survey Will Solano- Indiana Geological Survey Agnieszka Drobniak- Indiana Geological Survey This research is underwritten by the U. S. Dept. of Energy, Office of Fossil Energy, Regional Carbon Sequestration Partnership Program, the Illinois Office of Coal Development, and the Illinois State, Indiana and Kentucky Geological Surveys 2
Outline Illinois Basin Geology Illinois Basin Coal Properties CO 2 Injection Modeling and Basin Volumetrics DOE Phase II CO 2 Injection Plans 3
Illinois Basin Geology Geological Section Seals Coal Depth & Elevation Aggregate Net Coal Thickness Cleat Orientation and Stress Field 4
How much coal? Illinois 211 billion tons Indiana W KY 59 billion tons 39 billion tons IL Basin 309 billon tons, the largest bituminous coal reserve in the Nation 5
Illinois Pennsylvanian Rocks Shale Seals Throughout Major Coal Gas/CO 2 Injection Targets 6
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N-S S Cross Section of Coal-bearing Strata in Illinois By Christopher Korose, Jamie McBeth, and Colin Treworgy, ISGS 8
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Average net thickness of major seams > 1.5 ft is 15 ft, locally more than 25 ft. Thickness of individual main seams: mean = 4.4 ft P10 = 6.3 The major seams are well behaved stratigraphically 12
IL Basin Coal Cleat Orientation Present Stress Field 13
Coal Physical Conditions Temperature- 55 o F to 84 o F Depth- surface to 1500 ft. Pressure (hydrostatic)- 0 to 650 psi Water Salinity- fresh to 25,000 ppm tds 14
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Illinois Basin coals subcritical, gaseous phase of CO 17 2
Coal and Coal Gas Properties Gas Content Coal Gas Composition Coal Gas Isotopic Composition Permeability Adsorption Isotherms- CH 4 and CO 2 Thermal Maturity Moisture 18
IL and IN Coal Gas Contents IL & IN Depth vs Gc (dmmf) 250.0 Gc (scf/ton) Gc (scf/t) 200.0 150.0 100.0 Gc dmmf 2 Poly 50.0 0.0 0 200 400 600 800 1000 1200 1400 1600 Depth (ft) 19
Coal Canister Gas Composition (after atmospheric gas correction) Type Range (vol %) Mean (vol %) CH 4 50-96 76 C 2+ 0.0 4.8 1.2 N 2 0.0 51 20 CO 2 0.4 16.9 1.9 Produced Gas Sullivan Co. IN >97% CH 4 20
Coal Gas Isotopic Composition Delta DSMOW ( o /oo) -100.0-150.0-200.0-250.0-300.0-350.0 Microbial CO2 (reduction) transition Increasing maturity Thermogenic Microbial (fermentation) Bureau Clark Franklin Hon #9 Macoupin Richland Wasem #C-1 Jasper -400.0-90.00-80.00-70.00-60.00-50.00-40.00-30.00 Fields from Rice (1993) and Coleman et al. (1995) Delta 13C pdb ( o / oo ) 21
Hon #9 NE White County, IL Coal Perm from PT Tests Coal Depth Net Thick -ness (ft) Perm (md) Skin-Factor (dimensionless) Danville #7 760 2 33.7 n/a Herrin #6 807 5 4.3-4.9 Springfield #5 884 4 21.7-1.8 Survant #3 998 4 3.3-5 Colchester #2 1067 2 10.6-3.4 Davis 1113 5 14.1-0.3 22
md 1000 CBM Basin Comparison Permeability 100 10? 1 SJ DW BW PR ILB 23
Methane adsorption capacity scf/ton, daf 500 450 400 350 300 250 200 150 100 50 0 Range for Indiana coals 0 500 1000 1500 2000 Pressure (psi) Seel 33H 448 Seel 33H 452 Spring WM Spring CC Seel SDH UB Parke UB Parke 1 Dan AQ Dan FM UB Daviess LB Daviess Spring Sullivan Seel Sullivan MD-G Spr184 Knox Seel TH Seel 24
Carbon dioxide adsorption capacity 1000 scf/ton, daf 900 800 700 600 500 400 300 200 100 0 Range for Indiana coals 0 100 200 300 400 500 600 700 Pressure (psi) Seel 33H 448 Seel 33H 452 Spring WM Spring CC Seel SDH UB Parke UB Parke 1 Dan AQ Dan FM Spring Sullivan Seel Sullivan MD-G Spr184 Knox Seel TH Seel 25
Indiana coal high volatile bituminous rank 20010803 B1 Rainbou Adsorption (SCF/Ton, DAF) 700 600 500 400 300 200 100 0 4.59 CO2 CH4 0 200 400 600 800 1000 1200 1400 Pressure (PSI) Example of CO 2 and CH 4 adsorption isotherm 26
Modified from Meissner, 1984 0.4 0.6 0.8 1.0 KY Illinois Basin Indiana coals Coal Rank subbituminous high volatile bituminous C high volatile bituminous B high volatile bituminous A Coal Maturity (Rank, Ro, Moisture) Illinois Basin coals are high volatile bituminous rank 3 9 15 Maximum Thermogenic gas potential [m 3 /t] medium volatile bituminous 27
Vitrinite reflectance (R o %) map for the Springfield Coal 28
Low moisture areas favorable for CO 2 sequestration 29
CO 2 /ECBM Reservoir Simulation Reservoir simulation of CBM and CO 2 ECBM using COMET Flow model specifications of a typical Illinois Basin coal: ¼ of 80 acre injection pattern Thickness 4.2 ft Depth 700 ft Total Porosity 1% Permeability 15 and 50 md cases 30
CBM and ECBM COMET Flow Modeling High Permeability RF: 0.710, SF: 0.890, k: 50 md CO 2 Breakthrough: 546 days 935 Low Permeability RF: 0.029, SF: 0.330, k: 15md CO 2 Breakthrough: 1765 days 935 t: 550 days t: 550 days 31
CO 2 Storage and ECBM Volumetrics for Illinois Basin Coals considered: a) 300-500 - No SEQ, CBM locally b) 500-1000' and Unminable -18-42 inches thick available for SEQ, CBM and ECBM. Thicker coals not considered for CO 2 Storage or ECBM, but offer additional potential. c) >1000 all coals >1.5 considered Unminable and thus available for- SEQ, CBM, ECBM Method: Individual coals modeled then summed in GIS 32
Data for the entire Illinois Basin Illinois Basin Seam ECBM Recoverable CO 2 Storage CO 2 Storage (Bscf) (Tscf) (Mtonnes) Danville/Baker 807 8 440 Hymera/Jamestown/Paradise 200 2 110 Herrin 902 10 518 Springfield 1,251 13 717 Survant 1,081 11 582 Colchester 1,274 13 667 Seelyville/Davis 1,163 11 602 Illinois Basin TOTALS Illinois 6,032 62 3,300 Indiana 361 3 186 Kentucky 286 3 152 Total 6,680 68 3,638 P50 estimate for enhanced CH 4 production and CO 2 storage potentials in Illinois Basin coals Coals considered: a) coal 500-1000' deep and 18-42 inches thick b) coal >1000' deep and >18 inches thick (mined areas and coals less 500 excluded). 33
7 seams assessed! P50 estimates 3.6 billion tonnes total CO2 storage potential 34
7 seams assessed! P50 estimates 6.7 Tcf total ECBM recoverable! 35
MGSC Field Testing: The Heart of Phase II Six field tests proposed CBM at one of two sites Heavy oil (single well), immiscible, and miscible EOR at four sites; new drilling at two of these to optimize CO 2 flooding pattern One deep saline reservoir test, the Multi- Opportunity Sequestration Test (MOST) site with two major reservoir targets to 9,400 ft 36
Ethanol Plants CO2 Potential Sources: 3 Ethanol Plants Potential Test Sites: 2 coal seam sites 28 mature oil field sites for EOR 4 deep saline reservoir sites 37
CO 2 Injection Field Tests into One Coal Purpose: To determine the CO 2 injection and storage capability, and the ECBM recovery potential of Illinois coal Small Nitrogen Injection Test Small CO 2 Injection Test 30-Day CO 2 Test- Injection of up to 700 tons of CO 2 with 60 day soak 38
Coal Injection Test Design Coal Data Before Injection: Geology and Logs Desorption Adsorption Coal Gas Chem Monitor Well #1 butt Injection Well Monitor Well #2 face 1. Measure Pressure Transients to Calculate Changes in Permeability 2. Measure Recovered Gas Chemistry 3. Measure Injected and Recovered Gas Volumes 4. Seismic visualization? MMV Program: soil (vadose) gas Groundwater gas Atmospheric gas Pressure in two deep observation wells 39
MGSC Phase II Lab Studies 1. Investigate effects of CO 2 Adsorption Influence of moisture and ash Influence of maceral composition Influence of coal surface area Influence of temperature and pressure On physical and chemical properties of coal On CO 2 and CH 4 carbon isotopes with adsorption 2. Compare sorption characteristics in crushed and uncrushed coal 40
What are the factors controlling CO 2 sorption capacity of coals? Influence of moisture and ash Influence of maceral composition Significance of sampling time Influence of surface area, and Influence of temperature and pressure. 41
Does CO 2 sorption capacity measured on crushed samples reflect that in solid uncrushed coal? We will compare CO 2 sorption characteristics in crushed versus uncrushed coal at reservoir temperature and pressure conditions. This will be an experimental study in which we will use both our core apparatus and our new crushed coal apparatus. pressure vessel filter coal annular space D P D PO P I vent C W F G CO 2 E backpressureregulator Mac meter Gow- flow- vent vent 2 Y CO 2 B A 3 1 X safety H relief ISCOpump Z CH 4 P A N 2 Experimental Design: coalbed methane and carbon dioxide sorption on cylindrical blocks of coal; March 07, 2003. 42
How does CO 2 affect coal properties? - hardness and grindability - swelling/shrinking - surface area - pore size distribution - permeability - vitrinite reflectance and other optical characteristics 43
Are there any isotopic changes in CO 2 during sorption into the coal? We will perform multiple experiments at various pressures, different coal particle sizes, and equilibration times using our adsorption systems. 44
Summary Phase 1: Basinwide maps generated include coal quality (i.e. moisture, ash, etc.), coal thickness and structure Experimental tests (adsorption/desorption, reservoir simulations, isotope data) COMET and GIS-based sequestration potential calculations Phase 2: Field tests Analytical lab tests Modeling support 45
Midwest Geological Sequestration Consortium www.sequestration.org 46