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Relative Permeability: A Critical Parameter in Numerical Simulations of Multiphase Flow in Porous Media

Author

Listed:
  • Nathan Moodie

    (Carbon Science & Engineering Research Group, University of Utah, Salt Lake City, UT 84112, USA)

  • William Ampomah

    (New Mexico Tech, Socorro, NM 87801, USA)

  • Wei Jia

    (Carbon Science & Engineering Research Group, University of Utah, Salt Lake City, UT 84112, USA)

  • Brian McPherson

    (Carbon Science & Engineering Research Group, University of Utah, Salt Lake City, UT 84112, USA)

Abstract

Effective multiphase flow and transport simulations are a critical tool for screening, selection, and operation of geological CO 2 storage sites. The relative permeability curve assumed for these simulations can introduce a large source of uncertainty. It significantly impacts forecasts of all aspects of the reservoir simulation, from CO 2 trapping efficiency and phase behavior to volumes of oil, water, and gas produced. Careful consideration must be given to this relationship, so a primary goal of this study is to evaluate the impacts on CO 2 -EOR model forecasts of a wide range of relevant relative permeability curves, from near linear to highly curved. The Farnsworth Unit (FWU) is an active CO 2 -EOR operation in the Texas Panhandle and the location of our study site. The Morrow ‘B’ Sandstone, a clastic formation composed of medium to coarse sands, is the target storage formation. Results indicate that uncertainty in the relative permeability curve can impart a significant impact on model predictions. Therefore, selecting an appropriate relative permeability curve for the reservoir of interest is critical for CO 2 -EOR model design. If measured laboratory relative permeability data are not available, it must be considered as a significant source of uncertainty.

Suggested Citation

  • Nathan Moodie & William Ampomah & Wei Jia & Brian McPherson, 2021. "Relative Permeability: A Critical Parameter in Numerical Simulations of Multiphase Flow in Porous Media," Energies, MDPI, vol. 14(9), pages 1-14, April.
  • Handle: RePEc:gam:jeners:v:14:y:2021:i:9:p:2370-:d:541341
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    Citations

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    Cited by:

    1. Samuel Appiah Acheampong & William Ampomah & Don Lee & Angus Eastwood-Anaba, 2023. "Coupled Hydromechanical Modeling and Assessment of Induced Seismicity at FWU: Utilizing Time-Lapse VSP and Microseismic Data," Energies, MDPI, vol. 16(10), pages 1-24, May.
    2. William Ampomah & Brian McPherson & Robert Balch & Reid Grigg & Martha Cather, 2022. "Forecasting CO 2 Sequestration with Enhanced Oil Recovery," Energies, MDPI, vol. 15(16), pages 1-7, August.

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