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Development of a Permeability Formula for Tight and Shale Gas Reservoirs Based on Advanced High-Precision Lab Measurement Techniques

Author

Listed:
  • Paulina Krakowska-Madejska

    (Faculty of Geology, Geophysics and Environmental Protection, AGH University of Science and Technology, Al. Mickiewicza 30, 30-059 Krakow, Poland)

  • Edyta Puskarczyk

    (Faculty of Geology, Geophysics and Environmental Protection, AGH University of Science and Technology, Al. Mickiewicza 30, 30-059 Krakow, Poland)

  • Magdalena Habrat

    (Faculty of Geology, Geophysics and Environmental Protection, AGH University of Science and Technology, Al. Mickiewicza 30, 30-059 Krakow, Poland)

  • Paweł Madejski

    (Faculty of Mechanical Engineering and Robotics, AGH University of Science and Technology, Al. Mickiewicza 30, 30-059 Krakow, Poland)

  • Marek Dohnalik

    (Oil and Gas Institute—National Research Institute, Lubicz 25A, 31-503 Krakow, Poland)

  • Mariusz Jędrychowski

    (Faculty of Physics and Applied Computer Science, AGH University of Science and Technology, Al. Mickiewicza 30, 30-059 Krakow, Poland)

Abstract

Computed X-ray tomography (CT), together with pulse and pressure decay permeability methods were used to evaluate a formula for absolute reservoir permeability. For this reason, 62 core samples representing geological material of tight, gas-bearing sandstones, mudstones, limestones, and dolostones were studied. Samples were divided into two groups with lower and higher permeability values. Images of the pore space were processed and interpreted to obtain geometrical parameters of the objects (pores, microfractures) with 0.5 × 0.5 × 0.5 µm 3 voxel size. Statistical methods, which included basic statistical analysis, linear regression, and multiple linear regression analysis, were combined to evaluate the formula for absolute permeability. It appeared that the following parameters: Feret Breadth/Volume, Flatness/Anisotropy, Feret Max/Flatness, moments of inertia around middle principal axis I2/around longest principal axis I3, Anisotropy/Flatness, Flatness/Anisotropy provided the best results. The presented formula was obtained for a large set of data and is based only on the geometric parameters of the pore space. The novelty of the work is connected with the estimation of absolute permeability using only data from the CT method for tight rocks.

Suggested Citation

  • Paulina Krakowska-Madejska & Edyta Puskarczyk & Magdalena Habrat & Paweł Madejski & Marek Dohnalik & Mariusz Jędrychowski, 2021. "Development of a Permeability Formula for Tight and Shale Gas Reservoirs Based on Advanced High-Precision Lab Measurement Techniques," Energies, MDPI, vol. 14(9), pages 1-25, May.
    • Handle: RePEc:gam:jeners:v:14:y:2021:i:9:p:2628-:d:548558
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    References listed on IDEAS

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    1. Aliya Mukhametdinova & Andrey Kazak & Tagir Karamov & Natalia Bogdanovich & Maksim Serkin & Sergey Melekhin & Alexey Cheremisin, 2020. "Reservoir Properties of Low-Permeable Carbonate Rocks: Experimental Features," Energies, MDPI, vol. 13(9), pages 1-25, May.
    2. Paulina Krakowska & Paweł Madejski, 2019. "Research on Fluid Flow and Permeability in Low Porous Rock Sample Using Laboratory and Computational Techniques," Energies, MDPI, vol. 12(24), pages 1-17, December.
    3. Linxian Gong & Lei Nie & Yan Xu, 2020. "Geometrical and Topological Analysis of Pore Space in Sandstones Based on X-ray Computed Tomography," Energies, MDPI, vol. 13(15), pages 1-18, July.
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