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Characterizing the Microscopic Anisotropic Permeabilities of Tight Oil Reservoirs Impacted by Heterogeneous Minerals

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  • Ziqiang Wang

    (Institute of Unconventional Petroleum Science and Technology, China University of Petroleum, Beijing 102249, China
    Research Institute of Exploration and Development, Xinjiang Oilfield Company, Karamay 834000, China
    Xinjiang Key Laboratory of Shale Oil Exploration and Development, Karamay 834000, China)

  • Hongkui Ge

    (Institute of Unconventional Petroleum Science and Technology, China University of Petroleum, Beijing 102249, China)

  • Yun Wei

    (Research Institute of Exploration and Development, Xinjiang Oilfield Company, Karamay 834000, China)

  • Yi Wang

    (Research Institute of Exploration and Development, Xinjiang Oilfield Company, Karamay 834000, China)

  • Kerui Jia

    (Research Institute of Exploration and Development, Xinjiang Oilfield Company, Karamay 834000, China)

  • Ning Xu

    (Research Institute of Exploration and Development, Xinjiang Oilfield Company, Karamay 834000, China)

  • Yuankai Zhang

    (Research Institute of Exploration and Development, Xinjiang Oilfield Company, Karamay 834000, China)

  • Shuheng Du

    (School of Earth and Space Sciences, Peking University, Beijing 100871, China
    State Key Laboratory of Nonlinear Mechanics, Institute of Mechanics, Chinese Academy of Sciences, Beijing 100190, China
    School of Engineering Science, University of Chinese Academy of Sciences, Beijing 100049, China)

Abstract

This study aimed to reveal the anisotropic permeabilities of tight oil reservoirs impacted by heterogeneous minerals. SEM imaging, image processing, fractal calculation, microscopic reservoir modeling, and visual flow simulation were carried out to investigate the above problems. Results show that the variation coefficient of two-dimensional permeability for the studied tight reservoir samples ranges from 0.09 to 0.95, with an average value of 0.68. The penetration coefficient ranges from 1.16 to 2.64, with an average value of 2.13. The ratio of maximum to minimum permeability is between 1.25 and 7.67, with an average value of 5.62. The fluid flow in tight reservoirs has significant anisotropy comprising dominant flow through conductive channels. Flow in tight oil reservoirs tends to involve minor hydraulic fracturing with no proppant.

Suggested Citation

  • Ziqiang Wang & Hongkui Ge & Yun Wei & Yi Wang & Kerui Jia & Ning Xu & Yuankai Zhang & Shuheng Du, 2022. "Characterizing the Microscopic Anisotropic Permeabilities of Tight Oil Reservoirs Impacted by Heterogeneous Minerals," Energies, MDPI, vol. 15(18), pages 1-13, September.
    • Handle: RePEc:gam:jeners:v:15:y:2022:i:18:p:6552-:d:909480
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    References listed on IDEAS

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    1. Michael Chuks Halim & Hossein Hamidi & Alfred R. Akisanya, 2021. "Minimizing Formation Damage in Drilling Operations: A Critical Point for Optimizing Productivity in Sandstone Reservoirs Intercalated with Clay," Energies, MDPI, vol. 15(1), pages 1-30, December.
    2. Zhengwen Zeng, 2021. "Frac-n-Flow Testing to Screen Brittle Fracture Stages in Wolfcamp Formation, Permian Basin, USA," Energies, MDPI, vol. 14(17), pages 1-24, September.
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    Cited by:

    1. Shaojie Zhang & Feng Zhu & Jin Xu & Peng Liu & Shangbin Chen & Yang Wang, 2023. "Spontaneous Imbibition and Core Flooding Experiments of Enhanced Oil Recovery in Tight Reservoirs with Surfactants," Energies, MDPI, vol. 16(4), pages 1-11, February.
    2. Sergey Krivoshchekov & Alexander Kochnev & Nikita Kozyrev & Evgeny Ozhgibesov, 2022. "Factoring Permeability Anisotropy in Complex Carbonate Reservoirs in Selecting an Optimum Field Development Strategy," Energies, MDPI, vol. 15(23), pages 1-12, November.

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