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Simulation Analysis of CO 2 -EOR Process and Feasibility of CO 2 Storage during EOR

Author

Listed:
  • Maja Arnaut

    (Department of Petroleum and Gas Engineering and Energy, Faculty of Mining, Geology, and Petroleum Engineering, Pierottijeva 6, 10 000 Zagreb, Croatia)

  • Domagoj Vulin

    (Department of Petroleum and Gas Engineering and Energy, Faculty of Mining, Geology, and Petroleum Engineering, Pierottijeva 6, 10 000 Zagreb, Croatia)

  • Gabriela José García Lamberg

    (Independent Researcher, Santiago 8320000, Chile)

  • Lucija Jukić

    (Department of Petroleum and Gas Engineering and Energy, Faculty of Mining, Geology, and Petroleum Engineering, Pierottijeva 6, 10 000 Zagreb, Croatia)

Abstract

In this study, oil production and retention were observed and compared in 72 reservoir simulation cases, after which an economic analysis for various CO 2 and oil prices was performed. Reservoir simulation cases comprise different combinations of water alternating gas (WAG) ratios, permeabilities, and well distances. These models were set at three different depths; thus different pressure and temperature conditions, to see the impact of miscibility on oil production and CO 2 sequestration. Those reservoir conditions affect oil production and CO 2 retention differently. The retention trend dependence on depth was not monotonic—optimal retention relative to the amount of injected CO 2 could be achieved at middle depths and mediocre permeability as well. Results reflecting different reservoir conditions and injection strategies are shown, and analysis including the utilization factor and the net present value was conducted to examine the feasibility of different scenarios. The analysis presented in this paper can serve as a guideline for multiparameter analysis and optimization of CO 2 -enhanced oil recovery (EOR) with a WAG injection strategy.

Suggested Citation

  • Maja Arnaut & Domagoj Vulin & Gabriela José García Lamberg & Lucija Jukić, 2021. "Simulation Analysis of CO 2 -EOR Process and Feasibility of CO 2 Storage during EOR," Energies, MDPI, vol. 14(4), pages 1-28, February.
    • Handle: RePEc:gam:jeners:v:14:y:2021:i:4:p:1154-:d:503520
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    References listed on IDEAS

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    1. Ren, Bo & Duncan, Ian J., 2019. "Reservoir simulation of carbon storage associated with CO2 EOR in residual oil zones, San Andres formation of West Texas, Permian Basin, USA," Energy, Elsevier, vol. 167(C), pages 391-401.
    2. Tapia, John Frederick D. & Lee, Jui-Yuan & Ooi, Raymond E.H. & Foo, Dominic C.Y. & Tan, Raymond R., 2016. "Optimal CO2 allocation and scheduling in enhanced oil recovery (EOR) operations," Applied Energy, Elsevier, vol. 184(C), pages 337-345.
    3. McCollum, David L & Ogden, Joan M, 2006. "Techno-Economic Models for Carbon Dioxide Compression, Transport, and Storage & Correlations for Estimating Carbon Dioxide Density and Viscosity," Institute of Transportation Studies, Working Paper Series qt1zg00532, Institute of Transportation Studies, UC Davis.
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    1. Naghizadeh, Arefeh & Jafari, Saeed & Norouzi-Apourvari, Saied & Schaffie, Mahin & Hemmati-Sarapardeh, Abdolhossein, 2024. "Multi-objective optimization of water-alternating flue gas process using machine learning and nature-inspired algorithms in a real geological field," Energy, Elsevier, vol. 293(C).

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