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Screening Criteria for Geologic CO2 Sequestration
Abstract |
Stratigraphic Column |
Site Selection
Coal Beds |
Oil Reservoirs |
Enhanced Oil Recovery |
Saline Aquifers |
Geologic Model
S.M. Frailey, H.E. Leetaru, R.J. Finley, S.R. Gustison, C.P. Korose, and D.A. Garner (Illinois State Geological Survey), with J. Rupp (Indiana Geological Survey) and J. Drahovzal (Kentucky Geological Survey). MGSC_criteria.pdf (7.2 M)
Abstract
The Illinois Basin includes the three major carbon dioxide (CO2) sequestration reservoir types: saline aquifers, oil reservoirs and coal seams. Screening criteria were developed, to identify a subset of geologic formations to consider for detailed characterization studies for reservoir-specific sequestration. The criteria categorize the reservoirs with the highest, moderate, and lowest CO2 geologic storage potential.
The ideal geologic formation for CO2 sequestration offers large storage capacity per unit of reservoir volume, with a caprock that prohibits vertical migration of CO2. In the case of oil reservoirs and coal seams, enhanced oil recovery and coalbed methane production opportunities exist.
The criteria were divided into two general categories, general criteria and geologic formation specific criteria. Examples of general criteria include caprock integrity and seismicity. Examples of formation-specific criteria are pressure and temperature for miscible/immiscible CO2 enhanced oil recovery and subsurface mining potential for coal.
Geographic Information System (GIS) software is used to integrate key criteria and identify areas with the greatest geologic sequestration potential.
Conclusions
Pressure and temperature criteria are required for all formation types to determine CO2 phase behavior (vapor, liquid, critical fluid) and CO2 fluid properties (density, coal adsorption, and solubility in water and oil). Accessible pore volumes (area, thickness, porosity, irreducible saturation, flood efficiency) are required for estimating CO2 sequestered volumes. In oil reservoirs, immiscible or miscible CO2 flooding conditions that determine CO2 sequestered volume and EOR potential must be defined on a reservoir-by-reservoir basis.
References
Beeson, D.M. and G.D. Ortloff, 1959, Laboratory Investigation of the Water-Driven Carbon Dioxide Process for Oil Recovery, trans., AIME 216, p. 388–391.
Baroni, M., J. Baroni, B.Miller, D. Blake, 1995, Applications of Advanced Petroleum Production Technology and Water Alternating Gas Injection for Enhanced Oil Recovery - Mattoon Oil Field, Illinois, Final Report for U.S. Department of Energy, DE-FC22-93BC 14955, U.S. Department of Energy, Metairie Site Office, New Orleans, Louisiana, 89 p.
Illinois State Geological Survey |
Indiana Geological Survey |
Kentucky Geological Survey
National Energy Technology Laboratory