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Understanding the carbon dioxide sequestration in low‐permeability saline aquifers in the Ordos Basin with numerical simulations

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  • Jian Xie
  • Keni Zhang
  • Litang Hu
  • Yongsheng Wang
  • Maoshan Chen

Abstract

A carbon dioxide (CO 2 ) capture and storage demonstration project was started in 2010 by injecting around 100 000 tonnes of super‐critical CO 2 per annum into a set of very low‐permeability sandstone at depths of more than 1600 m in the northeastern Ordos Basin, China. Based on the site‐specific geology and the observational data, a numerical injection model was developed in order to understand the hydrodynamic behavior of CO 2 in the subsurface for evaluating reservoir performance. The results show that the model reasonably described the spreading of the CO 2 plume. The Triassic Liujiagou sandstone aquifer is the most favorable storage formation for CO 2 sequestration at the site of interest. After three years of injection of CO 2 , the maximum lateral migration distance of CO 2 plume is about 550 m and the pressure build‐up is about 13 MPa in the Liujiagou formation for the actual injection simulation. The major storage layer is at depths of 1690–1699 m, which contributes around 80% of injectivity of the entire reservoir system. The leakage of CO 2 into the geological seals is negligible (>0.1%) over the entire simulation period. Regardless of the relatively good fit during the calibration period, the model overestimated the pressures associated with the injection thereafter. © 2015 Society of Chemical Industry and John Wiley & Sons, Ltd

Suggested Citation

  • Jian Xie & Keni Zhang & Litang Hu & Yongsheng Wang & Maoshan Chen, 2015. "Understanding the carbon dioxide sequestration in low‐permeability saline aquifers in the Ordos Basin with numerical simulations," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 5(5), pages 558-576, October.
    • Handle: RePEc:wly:greenh:v:5:y:2015:i:5:p:558-576
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    File URL: http://hdl.handle.net/10.1002/ghg.1499
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    References listed on IDEAS

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    1. Ghomian, Yousef & Pope, Gary A. & Sepehrnoori, Kamy, 2008. "Reservoir simulation of CO2 sequestration pilot in Frio brine formation, USA Gulf Coast," Energy, Elsevier, vol. 33(7), pages 1055-1067.
    2. Bob van der Zwaan & Reyer Gerlagh, 2008. "The Economics of Geological CO2 Storage and Leakage," Working Papers 2008.10, Fondazione Eni Enrico Mattei.
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    1. Cai Li & Keni Zhang & Chaobin Guo & Jian Xie & Jing Zhao & Xia Li & Federico Maggi, 2017. "Impacts of relative permeability hysteresis on the reservoir performance in CO 2 storage in the Ordos Basin," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 7(2), pages 259-272, April.
    2. Jafari, Mohammad & Cao, Shuang Cindy & Jung, Jongwon, 2017. "Geological CO2 sequestration in saline aquifers: Implication on potential solutions of China’s power sector," Resources, Conservation & Recycling, Elsevier, vol. 121(C), pages 137-155.
    3. Li, Yi & Yu, Hao & Li, Yi & Liu, Yaning & Zhang, Guijin & Tang, Dong & Jiang, Zhongming, 2020. "Numerical study on the hydrodynamic and thermodynamic properties of compressed carbon dioxide energy storage in aquifers," Renewable Energy, Elsevier, vol. 151(C), pages 1318-1338.
    4. Jun Li & Raheel Ahmed & Xiaochun Li, 2018. "Thermodynamic Modeling of CO 2 -N 2 -O 2 -Brine-Carbonates in Conditions from Surface to High Temperature and Pressure," Energies, MDPI, vol. 11(10), pages 1-18, October.
    5. 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.
    6. Bing Bai & Xiaochun Li & Haiqing Wu & Yongsheng Wang & Mingze Liu, 2017. "A methodology for designing maximum allowable wellhead pressure for CO 2 injection: application to the Shenhua CCS demonstration project, China," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 7(1), pages 158-181, February.

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