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A Review of CO 2 -Enhanced Oil Recovery with a Simulated Sensitivity Analysis

Author

Listed:
  • Mandadige Samintha Anne Perera

    (Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia)

  • Ranjith Pathegama Gamage

    (Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia)

  • Tharaka Dilanka Rathnaweera

    (Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia)

  • Ashani Savinda Ranathunga

    (Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia)

  • Andrew Koay

    (Department of Civil Engineering, Deep Earth Energy Laboratory, Monash University, Building 60, Melbourne 3800, Victoria, Australia)

  • Xavier Choi

    (Commonwealth Scientific and Industrial Research Organisation (CSIRO), Ian Wark Laboratory, Clayton 3168, Victoria, Australia)

Abstract

This paper reports on a comprehensive study of the CO 2 -EOR (Enhanced oil recovery) process, a detailed literature review and a numerical modelling study. According to past studies, CO 2 injection can recover additional oil from reservoirs by reservoir pressure increment, oil swelling, the reduction of oil viscosity and density and the vaporization of oil hydrocarbons. Therefore, CO 2 -EOR can be used to enhance the two major oil recovery mechanisms in the field: miscible and immiscible oil recovery, which can be further increased by increasing the amount of CO 2 injected, applying innovative flood design and well placement, improving the mobility ratio, extending miscibility, and controlling reservoir depth and temperature. A 3-D numerical model was developed using the CO 2 -Prophet simulator to examine the effective factors in the CO 2 -EOR process. According to that, in pure CO 2 injection, oil production generally exhibits increasing trends with increasing CO 2 injection rate and volume (in HCPV (Hydrocarbon pore volume)) and reservoir temperature. In the WAG (Water alternating gas) process, oil production generally increases with increasing CO 2 and water injection rates, the total amount of flood injected in HCPV and the distance between the injection wells, and reduces with WAG flood ratio and initial reservoir pressure. Compared to other factors, the water injection rate creates the minimum influence on oil production, and the CO 2 injection rate, flood volume and distance between the flood wells have almost equally important influence on oil production.

Suggested Citation

  • Mandadige Samintha Anne Perera & Ranjith Pathegama Gamage & Tharaka Dilanka Rathnaweera & Ashani Savinda Ranathunga & Andrew Koay & Xavier Choi, 2016. "A Review of CO 2 -Enhanced Oil Recovery with a Simulated Sensitivity Analysis," Energies, MDPI, vol. 9(7), pages 1-22, June.
    • Handle: RePEc:gam:jeners:v:9:y:2016:i:7:p:481-:d:72595
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    References listed on IDEAS

    as
    1. Vladimir Alvarado & Eduardo Manrique, 2010. "Enhanced Oil Recovery: An Update Review," Energies, MDPI, vol. 3(9), pages 1-47, August.
    2. Höök, Mikael & Hirsch, Robert & Aleklett, Kjell, 2009. "Giant oil field decline rates and their influence on world oil production," Energy Policy, Elsevier, vol. 37(6), pages 2262-2272, June.
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    Cited by:

    1. Aly A Hamouda & Nikhil Bagalkot, 2019. "Effect of Salts on Interfacial Tension and CO 2 Mass Transfer in Carbonated Water Injection," Energies, MDPI, vol. 12(4), pages 1-17, February.
    2. Jamil Fadi El-Masry & Kamel Fahmi Bou-Hamdan & Azza Hashim Abbas & Dmitriy A. Martyushev, 2023. "A Comprehensive Review on Utilizing Nanomaterials in Enhanced Oil Recovery Applications," Energies, MDPI, vol. 16(2), pages 1-28, January.
    3. Aminu, Mohammed D. & Nabavi, Seyed Ali & Rochelle, Christopher A. & Manovic, Vasilije, 2017. "A review of developments in carbon dioxide storage," Applied Energy, Elsevier, vol. 208(C), pages 1389-1419.
    4. Ladislane dos Santos Bastos & Igor Emanuel da Silva Lins & Gloria Meyberg Nunes Costa & Silvio Alexandre Beisl Vieira de Melo, 2022. "A Comprehensive Simulation Study of Physicochemical and Geochemical Interactions on Immiscible CO 2 -LSWAG Injection in Carbonates," Energies, MDPI, vol. 16(1), pages 1-23, December.
    5. Xie, Huaxiao & Liang, Dong & Peng, Hao & Wei, Xinru & Zhao, Jiale & Fu, Jinman & Zhang, Jun & Yan, Youguo, 2025. "Insight into sweeping and oil washing mechanisms in CO2 immiscible and miscible flooding: A study of computational fluid dynamics," Energy, Elsevier, vol. 334(C).
    6. Lou, Benkui & Li, Shuxia & Sun, Hao & Liu, Lu & Guo, Yang, 2025. "Study on the factors influencing CO2 hydrate sequestration in CH4 hydrate-bearing reservoirs," Energy, Elsevier, vol. 323(C).

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