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Assessing the combined influence of fluid-rock interactions on reservoir properties and injectivity during CO2 storage in saline aquifers

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  • Cui, Guodong
  • Wang, Yi
  • Rui, Zhenhua
  • Chen, Bailian
  • Ren, Shaoran
  • Zhang, Liang

Abstract

Complex fluid-rock interactions can occur during the injection of carbon dioxide (CO2) into saline aquifers for sequestration, which may affect CO2 injectivity and storage capacity. In this paper, a comprehensive reactive transport model is established to analyze salt precipitation, CO2-water-rock geochemical reactions, and their effects on reservoir physical properties and injectivity. In addition, sensitivity analyses are conducted to investigate the main factors that affect fluid-rock interactions and injectivity with relevance for site selection for CO2 storage. Results show that the back flow of formation water not only affects the salt precipitation but also affects the CO2-water-rock geochemical reactions, resulting in salt and calcite precipitations mainly occurring in the dry-out zone. However, most of the mineral dissolution/precipitation caused by CO2-water-rock reaction occurs in the two-phase and aqueous-phase zones, and their effect on reservoir porosity and permeability are small. A considerable amount of sodium chloride precipitates in the dry-out zone as brine is drawn by capillary action into this zone, with significant consequences for porosity, permeability and injectivity. The injection rate, salinity, capillary pressure–saturation relationships, and reservoir permeability strongly affect the distribution of salt precipitation. Moderate injection rates, salinities, capillary pressures, and permeabilities all lead to favorable CO2 injectivity.

Suggested Citation

  • Cui, Guodong & Wang, Yi & Rui, Zhenhua & Chen, Bailian & Ren, Shaoran & Zhang, Liang, 2018. "Assessing the combined influence of fluid-rock interactions on reservoir properties and injectivity during CO2 storage in saline aquifers," Energy, Elsevier, vol. 155(C), pages 281-296.
    • Handle: RePEc:eee:energy:v:155:y:2018:i:c:p:281-296
    DOI: 10.1016/j.energy.2018.05.024
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    References listed on IDEAS

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    1. Liu, Yongge & Hou, Jian & Zhao, Haifeng & Liu, Xiaoyu & Xia, Zhizeng, 2018. "A method to recover natural gas hydrates with geothermal energy conveyed by CO2," Energy, Elsevier, vol. 144(C), pages 265-278.
    2. Rui, Zhenhua & Wang, Xiaoqing & Zhang, Zhien & Lu, Jun & Chen, Gang & Zhou, Xiyu & Patil, Shirish, 2018. "A realistic and integrated model for evaluating oil sands development with Steam Assisted Gravity Drainage technology in Canada," Applied Energy, Elsevier, vol. 213(C), pages 76-91.
    3. Cui, Guodong & Zhang, Liang & Ren, Bo & Enechukwu, Chioma & Liu, Yanmin & Ren, Shaoran, 2016. "Geothermal exploitation from depleted high temperature gas reservoirs via recycling supercritical CO2: Heat mining rate and salt precipitation effects," Applied Energy, Elsevier, vol. 183(C), pages 837-852.
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