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A New Relative Permeability Characterization Method Considering High Waterflooding Pore Volume

Author

Listed:
  • Guangfeng Qi

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Jingang Zhao

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Hu He

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Encheng Sun

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Xin Yuan

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Shuoliang Wang

    (Faculty of Engineering, School of Energy, China University of Geosciences, Beijing 100083, China)

Abstract

In the process of waterflooding development, high waterflooding PVs will make the fluid percolation in the reservoir more complicated, resulting in lower efficiency of waterflooding. High waterflooding PVs will affect the relative permeability and change the seepage law of oil–water two-phase flow in a high water-cut period. In this study, we performed high waterflooding PVs relative permeability experiments using nine natural cores. The unsteady measurement method is used to test the relative permeability curve. The results show that: (1) the relative permeability is affected by the waterflooding PVs, the recovery efficiency of 2000 waterflooding PVs is 10.72% higher than that of 50 waterflooding PVs on the core scale; (2) it makes water mobility increase sharply, while oil phase flow capacity remains low and decreases at high water cut stage. A new relative permeability characterization method considering high waterflooding PVs is established, which is applied to the numerical simulator. It shows that the remaining oil saturation of the high-permeability belt is higher than the calculation results of the traditional numerical simulator. It means that the injected water does not diffuse much into the low-permeability zone of the formation. The modified simulator is validated with the actual China offshore oilfield model. The numerical saturation of the key section of the passing well is in good agreement with the actual logging interpretation results, and the water cut curve fits better in the whole area. The modified simulator could predict oil production accurately after high waterflooding PVs treatment.

Suggested Citation

  • Guangfeng Qi & Jingang Zhao & Hu He & Encheng Sun & Xin Yuan & Shuoliang Wang, 2022. "A New Relative Permeability Characterization Method Considering High Waterflooding Pore Volume," Energies, MDPI, vol. 15(11), pages 1-16, May.
    • Handle: RePEc:gam:jeners:v:15:y:2022:i:11:p:3868-:d:822992
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    References listed on IDEAS

    as
    1. Baoyang Cheng & Junjian Li & Shuai Jiang & Chunhua Lu & Hang Su & Fuwei Yu & Hanqiao Jiang, 2021. "Pore-Scale Investigation of Microscopic Remaining Oil Variation Characteristic in Different Flow Rates Using Micro-CT," Energies, MDPI, vol. 14(11), pages 1-16, May.
    2. Congcong Li & Shuoliang Wang & Qing You & Chunlei Yu, 2021. "A New Measurement of Anisotropic Relative Permeability and Its Application in Numerical Simulation," Energies, MDPI, vol. 14(16), pages 1-18, August.
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