TY - JOUR A2 - 旭，金泽AU - 张，君AU - 李钰伟盟 - 李，魏盟 - 陈梓杰盟 - 赵，袁非盟 - 渝，发豪AU - 郑艳PY- 2020 DA - 2020年9月11日TI - 研究水力压裂网络传播行为在致密砂岩地层与水泥封闭天然裂缝SP - 8833324 VL - 2020 AB - 在致密砂岩形成的天然裂缝起到裂缝网络产生显著作用在水力压裂。这项工作提出了致密砂岩的实验模型与封闭胶结生裂缝。关闭胶结骨折（CCF）的方向对水力压裂（HF）的传播特性的影响是基于水力压裂试验，研究。用于模拟HF的传播的场缩放的数值模型是基于流动应力损伤（FSD）耦合方法建立。This model contains the discrete fracture network (DFN) generated by the Monte-Carlo method and is used to investigate the effects of CCFs’ distribution, CCFs’ strength, and in-situ stress anisotropy, injection rate, and fluid viscosity on the propagation behavior of fracture network. The results show that the distribution direction of CCFs is critical for the formation of complex HFs. When the angle between the horizontal maximum principal stress direction and the CCFs is in the range of 30° to 60°, the HF network is the most complex. There are many kinds of compound fracture propagation patterns, such as crossing, branching, and deflection. The increase of CCFs’ strength is not conducive to the generation of branched and deflected fractures. When the in-situ stress difference ranges from 3 MPa to 6 MPa, the HF network’s complexity and propagation range can be guaranteed simultaneously. The increase in the injection rate will promote the formation of the complex HF network. The proper increase of fracturing fluid viscosity can promote HF’s propagation. However, when the viscosity is too high, the complex HFs only appear around the wellbore. The research results can provide new insights for the hydraulic fracturing optimization design of naturally fractured tight sandstone formation. SN - 1468-8115 UR - https://doi.org/10.1155/2020/8833324 DO - 10.1155/2020/8833324 JF - Geofluids PB - Hindawi KW - ER -