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Quantitative assessment of CO 2 storage capacity by using of hydrogeochemical and isotope data for deep saline aquifers

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  • Yiman Li
  • Zhonghe Pang

Abstract

CO 2 sequestration in deep saline aquifers presents a viable option for CO 2 emissions mitigation while accurate evaluation of CO 2 storage capacity is central to effective site selection. Existing methods are mostly based on consideration of trapping mechanisms, which is problematic in accurate determination of the storage efficiency factor and exposes results to considerable error. Many studies simply adopt DOE figures, which can't represent diverse geological conditions across the globe. A new geochemical‐based method is proposed which considers CO 2 trapping states rather than trapping mechanisms. It is especially effective for site‐scale CO 2 storage capacity calculation with single injection well and a timeframe of a hundred to a thousand years. This method considers injected CO 2 trapped in forms of free state and soluble state, but excludes the mineral trapping state. Effective pore volume is calculated based on two simplified models of CO 2 plume within effective affecting radius in which trigonal pyramidal and cylindrical models represent minimum and maximum volume, respectively. Calculations of free CO 2 saturation and the ratio of dissolved inorganic carbonate contributed by CO 2 dissolution are used to calculate effective CO 2 storage capacity in forms of free and soluble state, respectively. Isotope and hydrogeochemical data changes pre‐ and post‐CO 2 injection are used to calculate free CO 2 saturation and ratio of dissolved inorganic carbonate contributed by CO 2 dissolution. Numerical simulation with calibration by measured values and calculation of CO 2 consumption per unit weight of rock is suggested to assess CO 2 trapped by mineral state at timeframe of tens of thousands years.© 2015 Society of Chemical Industry and John Wiley & Sons, Ltd

Suggested Citation

  • Yiman Li & Zhonghe Pang, 2015. "Quantitative assessment of CO 2 storage capacity by using of hydrogeochemical and isotope data for deep saline aquifers," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 5(5), pages 592-602, October.
    • Handle: RePEc:wly:greenh:v:5:y:2015:i:5:p:592-602
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    File URL: http://hdl.handle.net/10.1002/ghg.1505
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    References listed on IDEAS

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    1. Emberley, S. & Hutcheon, I. & Shevalier, M. & Durocher, K. & Gunter, W.D. & Perkins, E.H., 2004. "Geochemical monitoring of fluid-rock interaction and CO2 storage at the Weyburn CO2-injection enhanced oil recovery site, Saskatchewan, Canada," Energy, Elsevier, vol. 29(9), pages 1393-1401.
    2. Labus, Krzysztof & Bujok, Petr, 2011. "CO2 mineral sequestration mechanisms and capacity of saline aquifers of the Upper Silesian Coal Basin (Central Europe) - Modeling and experimental verification," Energy, Elsevier, vol. 36(8), pages 4974-4982.
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    1. Yiman Li & Zhonghe Pang, 2017. "Hydrogeochemical characteristics of deep saline aquifers in sedimentary basins in China and implications for CO 2 geological storage with emphasis on total dissolved solids (TDS) and water type," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 7(1), pages 53-64, February.

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