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Numerical Analysis on the Formation of Fracture Network during the Hydraulic Fracturing of Shale with Pre-Existing Fractures

Author

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  • Jianming He

    (Key Laboratory of Shale Gas and Geoengineering, Institute of Geology and Geophysics, Chinese Academy of Sciences, Beijing 100029, China
    College of Earth Science, University of Chinese Academy of Sciences, Beijing 100049, China)

  • Zhaobin Zhang

    (Key Laboratory of Shale Gas and Geoengineering, Institute of Geology and Geophysics, Chinese Academy of Sciences, Beijing 100029, China)

  • Xiao Li

    (Key Laboratory of Shale Gas and Geoengineering, Institute of Geology and Geophysics, Chinese Academy of Sciences, Beijing 100029, China
    College of Earth Science, University of Chinese Academy of Sciences, Beijing 100049, China)

Abstract

In this paper, configurations of pre-existing fractures in cubic rock blocks were investigated and reconstructed for the modeling of experimental hydraulic fracturing. The fluid-rock coupling process of hydraulic fracturing was simulated based on the displacement discontinuities method. The numerical model was validated against the related laboratory experiments. The stimulated fracture configurations under different conditions can be clearly shown using the validated numerical model. First, a dominated fracture along the maximum principle stress direction is always formed when the stress difference is large enough. Second, there are less reopened pre-existing fractures, more newly formed fractures and less shear fractures with the increase of the cohesion value of pre-existing fractures. Third, the length of the stimulated shear fracture decreases rapidly with the increase of the friction coefficient, while the length of the tensile fracture has no correlation to the fiction coefficient. Finally, the increase of the fluid injection rate is favorable to the formation of a fracture network. The unfavorable effects of the large stress difference and the large cohesion of pre-existing fractures can be partly suppressed by an increase of the injection rate in the hydraulic fracturing treatment. The results of this paper are useful for understanding fracture propagation behaviors during the hydraulic fracturing of shale reservoirs with pre-existing fractures.

Suggested Citation

  • Jianming He & Zhaobin Zhang & Xiao Li, 2017. "Numerical Analysis on the Formation of Fracture Network during the Hydraulic Fracturing of Shale with Pre-Existing Fractures," Energies, MDPI, vol. 10(6), pages 1-10, May.
    • Handle: RePEc:gam:jeners:v:10:y:2017:i:6:p:736-:d:99362
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    References listed on IDEAS

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    1. Zhaobin Zhang & Xiao Li & Jianming He & Yanfang Wu & Bo Zhang, 2015. "Numerical Analysis on the Stability of Hydraulic Fracture Propagation," Energies, MDPI, vol. 8(9), pages 1-18, September.
    2. Zhaobin Zhang & Xiao Li, 2016. "Numerical Study on the Formation of Shear Fracture Network," Energies, MDPI, vol. 9(4), pages 1-16, April.
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    Cited by:

    1. Wan Cheng & Chunhua Lu & Bo Xiao, 2021. "Perforation Optimization of Intensive-Stage Fracturing in a Horizontal Well Using a Coupled 3D-DDM Fracture Model," Energies, MDPI, vol. 14(9), pages 1-18, April.
    2. Zenghui Liu & Changlong Du & Hongxiang Jiang & Kai Liu, 2017. "Analysis of Roadheader for Breaking Rock Containing Holes under Confining Pressures," Energies, MDPI, vol. 10(8), pages 1-19, August.
    3. Wenrui Shi & Xingzhi Wang & Yuanhui Shi & Aiguo Feng & Yu Zou & Steven Young, 2019. "Application of Dipole Array Acoustic Logging in the Evaluation of Shale Gas Reservoirs," Energies, MDPI, vol. 12(20), pages 1-17, October.
    4. Haijun Zhao & Dwayne D. Tannant & Fengshan Ma & Jie Guo & Xuelei Feng, 2019. "Investigation of Hydraulic Fracturing Behavior in Heterogeneous Laminated Rock Using a Micromechanics-Based Numerical Approach," Energies, MDPI, vol. 12(18), pages 1-21, September.

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