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High-fidelity reservoir simulations of enhanced gas recovery with supercritical CO2

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  • Patel, Milan J.
  • May, Eric F.
  • Johns, Michael L.

Abstract

EGR (Enhanced natural gas recovery) with CO2 sequestration offers the prospect of significant environmental and economic benefits by increasing gas recovery while simultaneously sequestering the greenhouse gas. Field-scale deployment is currently limited as the risks of contamination of the produced gas by injected CO2 are poorly understood. Reservoir simulations offer a method to quantify the risk but only if sufficiently accurate. For the first time, finite element simulations are presented for several EGR scenarios that incorporate the most accurate models available for fluid mixture and rock properties. Specifically, the GERG-2008 EOS (equation of state) is utilised to describe the supercritical fluid mixture's density, as are reference correlations linked to the most accurate experimental data available for diffusivity and viscosity. Realistic values for rock dispersivity and tortuosity determined from high-accuracy core-flooding and NMR (nuclear magnetic resonance) experiments were also integrated. The relative impacts of these properties were investigated for a benchmark layered reservoir with a quarter 5-spot well pattern. Recovery efficiency at different CO2 injection rates was also investigated and was determined to be the dominant consideration: a 100-fold rate increase improved recovery from 53% to 69% while CO2 breakthrough time decreased by less than expected. Collectively, these results emphasise the importance of accurate reservoir simulations for EGR.

Suggested Citation

  • Patel, Milan J. & May, Eric F. & Johns, Michael L., 2016. "High-fidelity reservoir simulations of enhanced gas recovery with supercritical CO2," Energy, Elsevier, vol. 111(C), pages 548-559.
    • Handle: RePEc:eee:energy:v:111:y:2016:i:c:p:548-559
    DOI: 10.1016/j.energy.2016.04.120
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    References listed on IDEAS

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    1. Ziabakhsh-Ganji, Zaman & Kooi, Henk, 2014. "Sensitivity of Joule–Thomson cooling to impure CO2 injection in depleted gas reservoirs," Applied Energy, Elsevier, vol. 113(C), pages 434-451.
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    Cited by:

    1. Patel, Milan J. & May, Eric F. & Johns, Michael L., 2017. "Inclusion of connate water in enhanced gas recovery reservoir simulations," Energy, Elsevier, vol. 141(C), pages 757-769.
    2. Sanchez-Vicente, Yolanda & Tay, Weparn J. & Al Ghafri, Saif Z. & Trusler, J.P. Martin, 2018. "Thermodynamics of carbon dioxide-hydrocarbon systems," Applied Energy, Elsevier, vol. 220(C), pages 629-642.
    3. Chuanliang Yan & Yuanfang Cheng & Fucheng Deng & Ji Tian, 2017. "Permeability Change Caused by Stress Damage of Gas Shale," Energies, MDPI, vol. 10(9), pages 1-11, September.
    4. 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.
    5. Abdirizak Omar & Mouadh Addassi & Volker Vahrenkamp & Hussein Hoteit, 2021. "Co-Optimization of CO 2 Storage and Enhanced Gas Recovery Using Carbonated Water and Supercritical CO 2," Energies, MDPI, vol. 14(22), pages 1-21, November.
    6. Abdolahi-Mansoorkhani, Hamed & Seddighi, Sadegh, 2019. "H2S and CO2 capture from gaseous fuels using nanoparticle membrane," Energy, Elsevier, vol. 168(C), pages 847-857.
    7. Ezekiel, Justin & Ebigbo, Anozie & Adams, Benjamin M. & Saar, Martin O., 2020. "Combining natural gas recovery and CO2-based geothermal energy extraction for electric power generation," Applied Energy, Elsevier, vol. 269(C).

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