Numerical investigation of hydraulic fracture network propagation in naturally fractured shale formations |
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| Institution: | 1. Unconventional Natural Gas Institute, China University of Petroleum, Beijing, 18 Fuxue Road, Changping, Beijing, China;2. College of Petroleum Engineering, China University of Petroleum, Beijing, 18 Fuxue Road, Changping, Beijing, China;3. PetroChina Research Institute of Petroleum Exploration and Development, Langfang, China;1. State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing), Beijing 102249, China;2. Langfang Branch of Research Institute of Petroleum Exploration & Development, Langfang 065007, China;1. College of Petroleum Engineering, China University of Petroleum, Beijing 102249, China;2. State Key Laboratory of Petroleum Resources and Prospecting, Beijing 102249, China;3. School of Civil and Environmental Engineering, Georgia Institute of Technology, GA 30332, USA;1. State Key Laboratory of Geomechanics and Geotechnical Engineering, Institute of Rock and Soil Mechanics, Chinese Academy of Sciences, Wuhan 430071, China;2. School of Civil and Resource Engineering, University of Western Australia, Crawley, WA, Australia;3. Carbon Resource Department, Idaho National Laboratory, Idaho Falls, ID, USA;4. Shell Exploration & Production Company, Houston, TX, USA |
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| Abstract: | Hydraulic fracture network (HFN) propagation in naturally fractured shale formations is investigated numerically using a 3D complex fracturing model based on the discrete element method. To account for the plastic deformation behavior of shales, the Drucker–Prager plasticity model is incorporated into the fracturing model. Parametric studies are then conducted for different Young's moduli, horizontal differential stresses, natural fracture (NF) properties, injection rates, and number and spacing of perforation clusters. Numerical results show that horizontal differential stress primarily determines the generation of a complex HFN. The plastic deformation of shale can reduce the stimulated reservoir volume; this is more obvious with Young's modulus of less than 20 GPa. In addition, a higher injection rate could largely increase the fracture complexity index (FCI). Moreover, increasing perforation cluster numbers per fracturing stage is beneficial for increasing the FCI, but it also increases the potential merging of neighboring fractures, which may lead to non-uniform development of HFN in far-wellbore regions. To achieve uniform development of HFN within a fracturing stage, the distribution of NFs should be fully considered. The results presented here may provide improved understanding of HFN generation and are favorable for optimizing fracturing treatment designs for shale formations. |
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| Keywords: | Shale Natural fracture Plastic deformation Hydraulic fracture network Stimulated reservoir volume |
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