An assessment of carbon sequestration options in the Mt. Simon of the Illinois Basin

Deep, saline water-bearing reservoirs offer the greatest potential for sequestration of large volumes of CO2. In the Midwest, the most significant saline reservoir is the Mt. Simon Sandstone. The Mt. Simon underlies one of the largest concentrations of coal fired power plants in the world... Full description

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Authors:Leetaru, H.; Frailey, S.M.; Morse, D.G.; Finley, R.J.
Volume Title:2007 AAPG annual convention & exhibition; abstracts volume
Source:Abstracts: Annual Meeting - American Association of Petroleum Geologists, Vol.2007, p.81; AAPG 2007 annual convention & exhibition, Long Beach, CA, April 1-4, 2007. Publisher: American Association of Petroleum Geologists and Society for Sedimentary Geology, Tulsa, OK, United States
Publication Date:2007
Note:In English
Subjects:Cambrian; Carbon sequestration; Discharge; Mount Simon Sandstone; Paleozoic; Risk assessment; Rock mechanics; Site exploration; Upper Cambrian; Illinois Basin; Midwest; United States
Record ID:2010013505
Copyright Information:GeoRef, Copyright 2020 American Geosciences Institute. Reference includes data supplied by American Association of Petroleum Geologists, Tulsa, OK, United States
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Deep, saline water-bearing reservoirs offer the greatest potential for sequestration of large volumes of CO2. In the Midwest, the most significant saline reservoir is the Mt. Simon Sandstone. The Mt. Simon underlies one of the largest concentrations of coal fired power plants in the world and this sandstone may provide one of the most significant carbon storage resources in the United States. An assessment of any potential Mt. Simon sequestration site must include knowledge of its depositional history, current structural configuration, and seal. An understanding of Mt. Simon geology alone is not adequate for addressing the public concerns for a safe repository for the permanent sequestration of CO2. For example, although there can be as much as 2,000 feet of Mt. Simon sandstone present, numerical flow modeling suggests that CO2 would migrate vertically and be primarily trapped in the uppermost part of the formation. Therefore, site assessment must also be concerned with the integrity of the caprock, formation capacity and injectivity, and vertical heterogeneities that would slow the upward migration of CO2 and allow greater interactions with CO2, water, and rock. Another public concern is whether the deep native saline waters would discharge into shallower outcrops, subcrops, or into freshwater regions of the same formation. Preliminary estimates using pressure transient theory indicates small pressure (1 psi) changes occur 30-40 miles away from a single well after 30 years of injecting 1 Mton/year.