Numerical investigation of the well shut-in and fracture uncertainty on fluid-loss and production performance in gas-shale reservoirs

The results indicate that, after incorporated with the imbibition hysteresis, water saturation of fracture is close to 1 even if the well has been shut in for a long period before flowback, and the saturation increases with the extending of shut-in during flowback. In addition, the rate fluid imbibition into the reservoir is extremely slow, and the invasion depth is less than 3 m after 100 days' shut-in. It is also concluded that shut-in duration is not proportional to gas production when we divide the shut-in situation into two cases. Therefore, it is inappropriate to judge that the longer the shut-in period is, the more favorable the production will be. For the fracture networks, we linked the density of NF with the half-length of HF to investigate the fracture complexities. The results show that more complicated fracture will greatly enhance gas production and reduce water recovery efficiency (flowback rate). Finally, different distribution patterns have different impact on well performance, but, the overall influence is much less than that of complexity.