Flowback Performance in Intensely Naturally Fractured Shale Gas Reservoirs

Abstract In an attempt to quantify post-stimulation flowback strategies, especially for high value wells with multi-stage stimulations, this study compares observed flowback production histories with multi-phase numerical simulation of flow in multiple fractures of various conductivities. A "fit for purpose" finite difference simulator is able to treat the numerical problem of extremely high transmissibility contrast ratios in the fracture patterns with multi-phase flow in the fractures. After simulation of several systems, it became apparent that the greatest behavioral contrast was between gas and liquid-filled fracture systems, regardless of the fracture intensity. The results from this study offer insight into the effect of high versus low rate or drawdown flowbacks in the two systems. It suggests potential stimulation strategies for the maximization of long-term productivity, especially in multi-stage stimulation scenarios.