This work addresses a field-scale model, in which the equations of multiphase/multicomponent fluid flow and geomechanics were fully coupled, to simulate natural gas successive storage/recovery processes in an Iranian sandstone depleted gas reservoir. First, a 1D mechanical earth model was developed for the reservoir wells and then converted to a geomechanical 3D model of the reservoir, through sequential Gaussian simulation. The fully coupled simulation of the fluid flow and geomechanics - validated by the analytical solution of the Mandel's problem - was then performed for ten years of gas injection/production cycles in a section of the reservoir between two wells. Variations of different parameters including porosity, permeability, subsidence and effective stress were investigated versus time and compared to those of the non-fully coupled model, within the 10-year period in the studied section of the reservoir. Moreover, the results of the fully coupled model were compared to that of the non-fully coupled one in terms of the gas production rate and bottom-hole pressure in a single well. The results showed that the maximum rate of gas production as well as the maximum bottom-hole pressure predicted by the fully coupled model were 9.5 and 15% lower than those of the non-fully coupled model, respectively.

这项工作解决了一个现场规模模型，该模型中多相/多组分流体流方程和地质力学方程完全耦合，以模拟伊朗砂岩贫化气藏中天然气的连续存储/回收过程。首先，为储层井开发了一维机械地球模型，然后通过顺序高斯模拟将其转换为储层的地质力学3D模型。然后，在两个井之间的一部分储层中，进行了长达十年的注气/采气周期，对流体流动和地质力学进行了完全耦合的模拟（通过Mandel问题的解析解决方案进行了验证）。不同参数的变化，包括孔隙率，渗透率，在储层研究区的10年内，研究了沉降和有效应力随时间的变化，并与非完全耦合模型的沉降和有效应力进行了比较。此外，就单口井的产气率和井底压力而言，将完全耦合模型的结果与非完全耦合模型的结果进行了比较。结果表明，完全耦合模型预测的最大产气率和最大井底压力分别比非完全耦合模型低了9.5％和15％。