CO2/brine/rock interactions in Lower Tuscaloosa formation

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.

doi:10.1002/ghg.1611

CO₂/brine/rock interactions in Lower Tuscaloosa formation

Journal Article · Wed Dec 07 00:00:00 EST 2016 · Greenhouse Gases: Science and Technology

DOI:https://doi.org/10.1002/ghg.1611· OSTI ID:1569756

Soong, Yee ^[1]; Howard, Bret H. ^[1]; Dilmore, Robert M. ^[1]; Haljasmaa, Igor ^[1]; Crandall, Dustin M. ^[1]; Zhang, Liwei ^[1]; Zhang, Wu ^[1]; Lin, Ronghong ^[1]; Irdi, Gino A. ^[1]; Romanov, Vyacheslav N. ^[1]; Mclendon, Thomas R. ^[1]

National Energy Technology Lab. (NETL), Pittsburgh, PA (United States)

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. Furthermore, these results have implications for performance of the storage interval, and the integrity of the seal in a CO₂ storage setting.

View Accepted Manuscript (DOE)

Research Organization:: National Energy Technology Laboratory (NETL), Pittsburgh, PA, Morgantown, WV, and Albany, OR (United States)

Sponsoring Organization:: USDOE

OSTI ID:: 1569756

Alternate ID(s):: OSTI ID: 1530427

Report Number(s):: NETL-PUB--20283

Journal Information:: Greenhouse Gases: Science and Technology, Journal Name: Greenhouse Gases: Science and Technology Journal Issue: 6 Vol. 6; ISSN 2152-3878

Publisher:: Society of Chemical Industry, WileyCopyright Statement

Country of Publication:: United States

Language:: English

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Cited By (3)

Application of a new reduced-complexity assessment tool to estimate CO ₂ and brine leakage from reservoir and above-zone monitoring interval (AZMI) through an abandoned well under geologic carbon storage conditions : Modeling and Analysis: Application of a new reduced-complexity assessment tool to estimate CO Zhang, Liwei; Dilmore, Robert; Huerta, Nicolas Greenhouse Gases: Science and Technology, Vol. 8, Issue 5 https://doi.org/10.1002/ghg.1813	journal	September 2018
Water–rock–CO ₂ interactions and CO ₂ storage of Honghe tight oil reservoirs: an experimental and simulation study He, Yingfu; Ji, Bingyu; Yang, Shu Greenhouse Gases: Science and Technology, Vol. 9, Issue 4 https://doi.org/10.1002/ghg.1875	journal	May 2019
Micro-CT Characterization of Wellbore Cement Degradation in SO ₄ ^2- –Bearing Brine under Geological CO ₂ Storage Environment Gan, Manguang; Zhang, Liwei; Miao, Xiuxiu Geofluids, Vol. 2019 https://doi.org/10.1155/2019/5164010	journal	November 2019

Figures / Tables (2)

Table 1(p. 29)

Table 2(p. 30)

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Related Subjects

58 GEOSCIENCES
CO2 sequestration
Tuscaloosa formation
chemical interaction
permeability
saline aquifer