Paper No. 8
Presentation Time: 9:00 AM-6:30 PM

GEOCHEMICAL AND MICROBIOLOGICAL INFLUENCES ON SEAL INTEGRITY DURING SC-CO2 EXPOSURE, ARBUCKLE AQUIFER, SE KANSAS


JACKSON, Christa1, SCHEFFER, Aimee2, FOWLE, David3, WATNEY, W. Lynn4, STRAZISAR, Brian5 and ROBERTS, Jennifer A.3, (1)Geology, University of Kansas, 1475 Jayhawk Blvd, Room 120, Lawrence, KS 66045, (2)Geology, ConocoPhillips, 600 N. Dairy Ashford PR 3060, Houston, TX 77079, (3)Geology, University of Kansas, Multidisciplinary Research Building, 2030 Becker Dr, Lawrence, KS 66047, (4)Kansas Geological Survey, Univ of Kansas, 1930 Constant Avenue, Lawrence, KS 66047, (5)Geomechanics and Flow Laboratory, National Energy Technology Laboratory, 626 Cochrans Mill Road, PO Box 10940, Pittsburgh, PA 15236, christa.jackson@ku.edu

The emission of CO2 and other greenhouse gases into the atmosphere has been linked to global climate change. In order to mitigate these effects, CO2 can be captured and injected into deep saline aquifers as a form of Geologic Carbon Storage (GCS). One such aquifer in Southeast Kansas, the Arbuckle dolomite, is being evaluated as a potential GCS site. The Arbuckle Group consists of cherty dolomite and is overlain by the Simpson Group and the Chattanooga Shale, which is considered to be the main aquifer seal. Above the Chattanooga Shale lies the Middle Pennsylvanian Cherokee Shale, considered a secondary seal. Reservoir brine and rock samples were collected via two wells drilled in Wellington, KS.

Under reservoir pressures and temperatures, the injected CO2 will be in the supercritical state, and will behave similarly to a buoyant liquid. This buoyancy will allow the supercritical CO2 (CO2 (sc)) to migrate upward through the aquifer and eventually come into contact with the caprock (Chattanooga Shale). In order to understand the potential geochemical and biological influences on reservoir materials and seal integrity upon exposure to CO2 (SC), a series of batch experiments was conducted. Powdered seal material, pyrite, and dolomite and collected brine with and without native microbial consortia were exposed to 100% pCO2 (SC) at reservoir temperatures and pressures (2500 psi and 50°C) for a duration of 5 to 45 days.

Aqueous geochemistry, XRD, and SEM reveal changes in mineralogy after CO2 exposure in experiments containing Chattanooga Shale and pyrite. While no mineralogical changes were indicated for experiments containing dolomite or Cherokee Shale, aqueous geochemistry reveals considerable changes were still occurring in these experiments. There were no significant differences between biotic and abiotic experiments, which may be a function of low reservoir biomass. The results indicate pyrite-bearing phases may precipitate secondary gypsum in the presence of CO2 and oxygenated reservoir brine. The precipitation of gypsum under these conditions could beneficially fill cracks and microfractures in the reservoir seal. Conversely, gypsum precipitation could fill valuable pore space near the injection site, resulting in a decrease in injection capability.