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Flow Simulation of Artificially Induced Microfractures Using Digital Rock and Lattice Boltzmann Methods

Author

Listed:
  • Yongfei Yang

    (Research Centre of Multiphase Flow in Porous Media, China University of Petroleum (East China), Qingdao 266580, Shandong, China)

  • Zhihui Liu

    (Research Centre of Multiphase Flow in Porous Media, China University of Petroleum (East China), Qingdao 266580, Shandong, China)

  • Jun Yao

    (Research Centre of Multiphase Flow in Porous Media, China University of Petroleum (East China), Qingdao 266580, Shandong, China)

  • Lei Zhang

    (Research Centre of Multiphase Flow in Porous Media, China University of Petroleum (East China), Qingdao 266580, Shandong, China)

  • Jingsheng Ma

    (Institute of Petroleum Engineering, Heriot-Watt University, Riccarton, Edinburgh EH14 4AS, UK)

  • S. Hossein Hejazi

    (Department of Chemical and Petroleum Engineering, University of Calgary, Calgary, Alberta T3A 6C9, Canada)

  • Linda Luquot

    (Hydrosciences Montpellier, Université Montpellier, CNRS, IRD, 300 Avenue du Pr. Emile Jeanbrau CC57, 34090 Montpellier, France)

  • Toussaint Dono Ngarta

    (Research Centre of Multiphase Flow in Porous Media, China University of Petroleum (East China), Qingdao 266580, Shandong, China)

Abstract

Microfractures have great significance in the study of reservoir development because they are an effective reserving space and main contributor to permeability in a large amount of reservoirs. Usually, microfractures are divided into natural microfractures and induced microfractures. Artificially induced rough microfractures are our research objects, the existence of which will affect the fluid-flow system (expand the production radius of production wells), and act as a flow path for the leakage of fluids injected to the wells, and even facilitate depletion in tight reservoirs. Therefore, the characteristic of the flow in artificially induced fractures is of great significance. The Lattice Boltzmann Method (LBM) was used to calculate the equivalent permeability of artificially induced three-dimensional (3D) fractures. The 3D box fractal dimensions and porosity of artificially induced fractures in Berea sandstone were calculated based on the fractal theory and image-segmentation method, respectively. The geometrical parameters (surface roughness, minimum fracture aperture, and mean fracture aperture), were also calculated on the base of digital cores of fractures. According to the results, the permeability lies between 0.071–3.759 (dimensionless LB units) in artificially induced fractures. The wide range of permeability indicates that artificially induced fractures have complex structures and connectivity. It was also found that 3D fractal dimensions of artificially induced fractures in Berea sandstone are between 2.247 and 2.367, which shows that the artificially induced fractures have the characteristics of self-similarity. Finally, the following relations were studied: (a) exponentially increasing permeability with increasing 3D box fractal dimension, (b) linearly increasing permeability with increasing square of mean fracture aperture, (c) indistinct relationship between permeability and surface roughness, and (d) linearly increasing 3D box fractal dimension with increasing porosity.

Suggested Citation

  • Yongfei Yang & Zhihui Liu & Jun Yao & Lei Zhang & Jingsheng Ma & S. Hossein Hejazi & Linda Luquot & Toussaint Dono Ngarta, 2018. "Flow Simulation of Artificially Induced Microfractures Using Digital Rock and Lattice Boltzmann Methods," Energies, MDPI, vol. 11(8), pages 1-17, August.
    • Handle: RePEc:gam:jeners:v:11:y:2018:i:8:p:2145-:d:164201
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    References listed on IDEAS

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    1. Yongfei Yang & Zhihui Liu & Zhixue Sun & Senyou An & Wenjie Zhang & Pengfei Liu & Jun Yao & Jingsheng Ma, 2017. "Research on Stress Sensitivity of Fractured Carbonate Reservoirs Based on CT Technology," Energies, MDPI, vol. 10(11), pages 1-15, November.
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    Cited by:

    1. Liming Zhang & Zekun Deng & Kai Zhang & Tao Long & Joshua Kwesi Desbordes & Hai Sun & Yongfei Yang, 2019. "Well-Placement Optimization in an Enhanced Geothermal System Based on the Fracture Continuum Method and 0-1 Programming," Energies, MDPI, vol. 12(4), pages 1-20, February.
    2. Jianchao Cai & Shuyu Sun & Ali Habibi & Zhien Zhang, 2019. "Emerging Advances in Petrophysics: Porous Media Characterization and Modeling of Multiphase Flow," Energies, MDPI, vol. 12(2), pages 1-5, January.
    3. Yaohao Guo & Lei Zhang & Guangpu Zhu & Jun Yao & Hai Sun & Wenhui Song & Yongfei Yang & Jianlin Zhao, 2019. "A Pore-Scale Investigation of Residual Oil Distributions and Enhanced Oil Recovery Methods," Energies, MDPI, vol. 12(19), pages 1-16, September.
    4. Qiang Wang & Jifang Wan & Langfeng Mu & Ruichen Shen & Maria Jose Jurado & Yufeng Ye, 2020. "An Analytical Solution for Transient Productivity Prediction of Multi-Fractured Horizontal Wells in Tight Gas Reservoirs Considering Nonlinear Porous Flow Mechanisms," Energies, MDPI, vol. 13(5), pages 1-20, March.
    5. Haiyuan Yang & Li Zhang & Ronghe Liu & Xianli Wen & Yongfei Yang & Lei Zhang & Kai Zhang & Roohollah Askari, 2019. "Thermal Conduction Simulation Based on Reconstructed Digital Rocks with Respect to Fractures," Energies, MDPI, vol. 12(14), pages 1-13, July.
    6. Xinling Li & Zeyun Jiang & Chao Min, 2019. "Quantitative Study of the Geometrical and Hydraulic Characteristics of a Single Rock Fracture," Energies, MDPI, vol. 12(14), pages 1-17, July.
    7. Zhihui Liu & Yongfei Yang & Yingwen Li & Jiaxue Li, 2021. "In Situ Deformation Analysis of a Fracture in Coal under Cyclic Loading and Unloading," Energies, MDPI, vol. 14(20), pages 1-16, October.
    8. Hai Sun & Lian Duan & Lei Liu & Weipeng Fan & Dongyan Fan & Jun Yao & Lei Zhang & Yongfei Yang & Jianlin Zhao, 2019. "The Influence of Micro-Fractures on the Flow in Tight Oil Reservoirs Based on Pore-Network Models," Energies, MDPI, vol. 12(21), pages 1-17, October.

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