--> --> Abstract: Characterization of Springfield Coal Member of the Carbondale Formation (Pennsylvanian) in a CO<sub>2</sub> Sequestration Pilot–Illinois Basin Tanquary Site, USA, by D. G. Morse, M. Mastalerz, J. A. Rupp, and S. Harpalani; #90095 (2009)

Datapages, Inc.Print this page

Characterization of Springfield Coal Member of the Carbondale Formation (Pennsylvanian) in a CO2 Sequestration Pilot–Illinois Basin Tanquary Site, USA

D. G. Morse1, M. Mastalerz2, J. A. Rupp2, and S. Harpalani3
1Illinois State Geological Survey, Champaign, IL 61820, [email protected]
2Indiana University, Indiana Geological Survey, Bloomington, IN 47405
3College of Engineering, Southern Illinois University, Carbondale, IL 62901

As part of the U.S. Department of Energy’s Regional Sequestration Partnership program, the potential for sequestering CO2 in the largest bituminous coal reserve in United States –the Illinois Basin– is being assessed at the Tanquary site in Wabash County, southeastern Illinois. To accomplish the main project objectives, which are to determine CO2 injection rates and storage capacity, we developed a detailed coal characterization program. The targeted Springfield Coal occurs at 900 ft depth, is 7 ft thick, and is of high volatile bituminous rank, having an average vitrinite reflectance (Ro) of 0.62%. Desorbed coal gas content in cores from four wells 50 to 100 ft apart varies from 150 to 210 scf/ton (dmmf) and consists generally of >92% CH4 with lesser amounts of N2 and then CO2. Adsorption isotherms indicate that at least three molecules of CO2 can be stored for each displaced CH4 molecule. Coal maceral composition affects sequestration potential and averaged 70.2% vitrinite, 3.6% liptinite, 13.9% inertinite, and 7.3% mineral matter. Well-developed coal cleats with 1 to 2 cm spacing contain partial calcite and/or kaolinite fillings that may decrease coal permeability. Shallow geophysical log induction curves show much higher resistivity in the lower part of the coal than the medium or deep curves because of invasion by freshwater drilling fluid, possibly indicating higher permeability. Gamma-ray and bulk density vary, reflecting differences in maceral, ash, and pyrite content. Because characteristics vary across the basin, it is critical to characterize injection site coals to best predict the potential for CO2 injection and storage capacity.


AAPG Search and Discovery Article #90095©2009 AAPG Eastern Section Meeting, Evansville, Indiana, September 20-22, 2009