CO2/brine/rock interactions in lower Tuscaloosa Formation

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doi: 10.1002/ghg.1611
Authors:Soong, Yee; Howard, Bret H.; Dilmore, Robert M.; Haljasmaa, Igor; Crandall, Dustin M.; Zhang, Liwei; Zhang, Wu; Lin, Ronghong; Irdi, Gino A.; Romanov, Vyacheslav N.; McLendon, Thomas R.
Author Affiliations:Primary:
U. S. Department of Energy, National Energy Technology Laboratory, Pittsburgh, PA, United States
Volume Title:Greenhouse Gases
Source:Greenhouse Gases, 6(6), p.824-837. Publisher: John Wiley & Sons, Sussex, United Kingdom. ISSN: 2152-3878
Publication Date:2016
Note:In English. 30 refs.; illus., incl. 2 tables, strat. col.
Summary:Saline aquifers are the largest potential continental geologic CO2 sequestration resource. Understanding of potential geochemically induced changes to the porosity and permeability of host CO2 storage and sealing formation rock will improve our ability to predict CO2 plume dynamics, storage capacity, and long-term reservoir behavior. Experiments exploring geochemical interactions of CO2/brine/rock on saline formations under CO2 sequestration conditions were conducted in a static system. Chemical interactions in core samples from the Lower Tuscaloosa formation from Jackson County, Mississippi, with exposure to CO2-saturated brine under sequestration conditions were studied through six months of batch exposure. The experimental conditions to which the core samples of Lower Tuscaloosa sandstone and Selma chalk were exposed to a temperature of 85°C, CO2 pressure of 23.8 MPa (3500 psig), while immersed in a model brine representative of Tuscaloosa Basin. Computed tomography (CT), X-Ray diffraction (XRD), Scanning Electron Microscopy (SEM), brine chemistry, and petrography analyses were performed before and after the exposure. Permeability measurements from the sandstone core sample before and after exposure showed a permeability reduction. No significant change of the permeability measurements was noticed for the core sample obtained from Selma chalk after it was exposed to CO2/brine for six months. These results have implications for performance of the storage interval, and the integrity of the seal in a CO2 storage setting. Copyright 2016 Society of Chemical Industry and John Wiley & Sons, Ltd
Subjects:Aquifers; Brines; Cap rocks; Carbon dioxide; Carbon sequestration; Carbonate rocks; Chalk; Clastic rocks; Contaminant plumes; Cretaceous; Ground water; Hydrodynamics; Injection; Mesozoic; Permeability; Pollution; Porosity; Reservoir rocks; Saline composition; Sandstone; Saturation; Sealing; Sedimentary rocks; Selma Group; Storage coefficient; Tuscaloosa Formation; Upper Cretaceous; Water-rock interaction; Jackson County Mississippi; Mississippi; United States; Cranfield Reservoir
Coordinates:N301800 N304300 W0882400 W0885300
Record ID:2020047712
Copyright Information:GeoRef, Copyright 2020 American Geosciences Institute. Reference includes data from John Wiley & Sons, Chichester, United Kingdom
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