Search Menu
DOE PAGES title logo U.S. Department of Energy
Office of Scientific and Technical Information
Search Scholarly Publications

Title: CO2/brine/rock interactions in Lower Tuscaloosa formation

Abstract

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 havemore » implications for performance of the storage interval, and the integrity of the seal in a CO2 storage setting.« less

Authors:
 [1];  [1];  [1];  [1];  [1];  [1];  [1];  [1];  [1];  [1];  [1]
+ Show Author Affiliations
  1. National Energy Technology Lab. (NETL), Pittsburgh, PA (United States)
Publication Date:
Research Org.:
National Energy Technology Laboratory (NETL), Pittsburgh, PA, Morgantown, WV, and Albany, OR (United States)
Sponsoring Org.:
USDOE
OSTI Identifier:
1569756
Report Number(s):
NETL-PUB-20283
Journal ID: ISSN 2152-3878
Resource Type:
Accepted Manuscript
Journal Name:
Greenhouse Gases: Science and Technology
Additional Journal Information:
Journal Volume: 6; Journal Issue: 6; Journal ID: ISSN 2152-3878
Publisher:
Society of Chemical Industry, Wiley
Country of Publication:
United States
Language:
English
Subject:
58 GEOSCIENCES; CO2 sequestration; Tuscaloosa formation; chemical interaction; permeability; saline aquifer

Citation Formats

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., and Mclendon, Thomas R. CO2/brine/rock interactions in Lower Tuscaloosa formation. United States: N. p., 2016. Web. doi:10.1002/ghg.1611.
Copy to clipboard
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. CO2/brine/rock interactions in Lower Tuscaloosa formation. United States. https://doi.org/10.1002/ghg.1611
Copy to clipboard
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., and Mclendon, Thomas R. Wed . "CO2/brine/rock interactions in Lower Tuscaloosa formation". United States. https://doi.org/10.1002/ghg.1611. https://www.osti.gov/servlets/purl/1569756.
Copy to clipboard
@article{osti_1569756,
title = {CO2/brine/rock interactions in Lower Tuscaloosa formation},
author = {Soong, Yee and Howard, Bret H. and Dilmore, Robert M. and Haljasmaa, Igor and Crandall, Dustin M. and Zhang, Liwei and Zhang, Wu and Lin, Ronghong and Irdi, Gino A. and Romanov, Vyacheslav N. and Mclendon, Thomas R.},
abstractNote = {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.},
doi = {10.1002/ghg.1611},
journal = {Greenhouse Gases: Science and Technology},
number = 6,
volume = 6,
place = {United States},
year = {Wed Dec 07 00:00:00 EST 2016},
month = {Wed Dec 07 00:00:00 EST 2016}
}
Copy to clipboard
Journal Article:
Free Publicly Available Full Text
Publisher's Version of Record
https://doi.org/10.1002/ghg.1611
Copyright Statement
Other availability
Search WorldCat Search WorldCat to find libraries that may hold this journal
Citation Metrics:
Cited by: 17 works
Citation information provided by
Web of Science

Figures / Tables:

Table 1 Table 1: XRD analysis of the Lower Tuscaloosa sandstone and the Selma chalk carbonate rock. (Analysis was performed by Weatherford Laboratories.)
All figures and tables (2 total)
Save / Share:
Export Metadata
Save to My Library
You must Sign In or Create an Account in order to save documents to your library.

Works referenced in this record:

US Department of Energy’s regional carbon sequestration partnership initiative: Update on validation and development phases
journal, January 2011

The conditions limiting CO2 storage in aquifers
journal, September 1993

Geochemistry of CO2 sequestration in the Jurassic Navajo Sandstone, Colorado Plateau, Utah
journal, February 2007

  • Parry, W. T.; Forster, Craig B.; Evans, J. P.
  • Environmental Geosciences, Vol. 14, Issue 2
  • DOI: 10.1306/eg.07120606004

Evaporite Caprock Integrity: An Experimental Study of Reactive Mineralogy and Pore-Scale Heterogeneity during Brine-CO 2 Exposure
journal, August 2012

  • Smith, Megan M.; Sholokhova, Yelena; Hao, Yue
  • Environmental Science & Technology, Vol. 47, Issue 1
  • DOI: 10.1021/es3012723

CO2–rock–brine interactions in Lower Tuscaloosa Formation at Cranfield CO2 sequestration site, Mississippi, U.S.A.
journal, January 2012

Influence of carbon dioxide on coal permeability determined by pressure transient methods
journal, January 2009

  • Siriwardane, Hema; Haljasmaa, Igor; McLendon, Robert
  • International Journal of Coal Geology, Vol. 77, Issue 1-2
  • DOI: 10.1016/j.coal.2008.08.006

An experimental investigation of trace element dissolution in carbon dioxide: Applications to the geological storage of CO2
journal, October 2011

A study of safe CO 2 storage capacity in saline aquifers: a numerical study : CO
journal, October 2012

  • Ranjith, P. G.; Perera, M. S. A.; Khan, E.
  • International Journal of Energy Research, Vol. 37, Issue 3
  • DOI: 10.1002/er.2954

Geochemical effects of CO2 sequestration in sandstones under simulated in situ conditions of deep saline aquifers
journal, September 2008

Physical and chemical characteristics of potential seal strata in regions considered for demonstrating geological saline CO2 sequestration
journal, February 2011

  • Griffith, Craig A.; Dzombak, David A.; Lowry, Gregory V.
  • Environmental Earth Sciences, Vol. 64, Issue 4
  • DOI: 10.1007/s12665-011-0911-5

X-ray microtomography characterization of porosity, permeability and reactive surface changes during dissolution
journal, March 2011

Reactivity of Mount Simon Sandstone and the Eau Claire Shale Under CO 2 Storage Conditions
journal, August 2012

  • Carroll, Susan A.; McNab, Walt W.; Dai, Zurong
  • Environmental Science & Technology, Vol. 47, Issue 1
  • DOI: 10.1021/es301269k

Understanding the significance of in situ coal properties for CO 2 sequestration: An experimental and numerical study : Coal properties for CO2 sequestration
journal, July 2013

  • De Silva, P. N. K.; Ranjith, P. G.
  • International Journal of Energy Research, Vol. 38, Issue 1
  • DOI: 10.1002/er.3062

Effect of contaminants from flue gas on CO 2 sequestration in saline formation : CO2 sequestration
journal, December 2013

  • Soong, Yee; Hedges, Sheila W.; Howard, Bret H.
  • International Journal of Energy Research, Vol. 38, Issue 9
  • DOI: 10.1002/er.3140

The dissolution kinetics of major sedimentary carbonate minerals
journal, July 2002

North Dakota lignite and Pittsburgh bituminous coal: a comparative analysis in application to CO<SUB align=right>2 sequestration
journal, January 2011

  • Haljasmaa, Igor V.; McLendon, T. Robert; Jikich, Sinisha A.
  • International Journal of Oil, Gas and Coal Technology, Vol. 4, Issue 3
  • DOI: 10.1504/IJOGCT.2011.040839

Modeling and simulation of carbon sequestration at Cranfield incorporating new physical models
journal, October 2013

  • Delshad, Mojdeh; Kong, Xianhui; Tavakoli, Reza
  • International Journal of Greenhouse Gas Control, Vol. 18
  • DOI: 10.1016/j.ijggc.2013.03.019

CO2 Sequestration in Saline Formation
journal, January 2014

  • Soong, Yee; Howard, Bret H.; Hedges, Sheila W.
  • Aerosol and Air Quality Research, Vol. 14, Issue 2
  • DOI: 10.4209/aaqr.2013.06.0195
    Sort by:
    [ × clear filter / sort ]

    Works referencing / citing this record:

    Water–rock–CO 2 interactions and CO 2 storage of Honghe tight oil reservoirs: an experimental and simulation study
    journal, May 2019

    • He, Yingfu; Ji, Bingyu; Yang, Shu
    • Greenhouse Gases: Science and Technology, Vol. 9, Issue 4
    • DOI: 10.1002/ghg.1875
      Sort by:
      [ × clear filter / sort ]

      Figures / Tables found in this record:

      Table 1 (p. 29)table
      Table 2 (p. 30)table
        [ × clear filter / sort ]
        Figures/Tables have been extracted from DOE-funded journal article accepted manuscripts.

        Similar Records in DOE PAGES and OSTI.GOV collections: