Production or injection of fluids from/in an underground storage site causes variations of pore pressure and stress states. These fluctuations significantly affect implications for hydraulic fracturing, wellbore integrity, top surface subsidence and heave, fault-reactivation, and stability of reservoir and caprock. Therefore, in order to keep optimal conditions during the process of gas injection and production, it is of paramount importance to have accurate estimates of the pore pressure. In this investigation, coupled fluid flow and geomechanical simulations, as well as rock mechanical tests, are performed on the Sarajeh field, Iran to investigate the geomechanical behavior of the Sarajeh reservoir during gas injection and production as well as estimate the caprock and reservoir integrity and evaluate the risk of fault reactivation. The results show up to −16 cm subsidence due to the production and 6 cm heave due to the injection. The critical pressures for the reservoir rock's failure and activation of the faults are 11,283 psi and 9986 psi, respectively, which make the operator able to store gas up to 2.2 and 1.9 times higher than the maximum reservoir pressure. Hydro-mechanical evaluation of the Sarajeh field determines essential information about the effect of gas injection and production for safe and successful seasonal gas storage.

从/从地下存储场所产生或注入流体会引起孔隙压力和应力状态的变化。这些波动显着影响了水力压裂，井眼完整性，顶面沉陷和起伏，断层复活以及储层和盖层的稳定性。因此，为了在气体注入和生产过程中保持最佳条件，对孔隙压力进行准确估算至关重要。在这项调查中，对伊朗萨拉热油田进行了耦合的流体流动和地质力学模拟以及岩石力学测试，以研究萨拉热储层在注气和生产过程中的地质力学行为，并估算了盖层和储层的完整性，以及评估故障重新激活的风险。结果显示，由于采油，沉降量高达-16 cm，而由于注入，沉降量高达6 cm。储层岩石破坏和断裂激活的临界压力分别为11283 psi和9986 psi，这使操作员能够存储的气体比最大储层压力高出2.2倍和1.9倍。Sarajeh油田的水力力学评估确定了有关注气和生产对安全和成功的季节性储气的影响的基本信息。