Pore pressure-stress analyses in stress-sensitive reservoirs investigate interactions between the in-situ stress and fluid flow; these interactions help or resist production, or conclude surface subsidence during production. Among the tools for these analyses, an iteratively coupled Geomechanics and fluid flow model provides an essential and reliable prediction for field planning and development. In this work, we implemented this model in an in-house, three dimensional, compositional reservoir simulator, UTCOMP, using modified Chin’s iterative coupling method. This development integrated a stand-alone Geomechanics module based on finite element method with the reservoir simulator, an advantage of our coupling algorithm, and improved our understanding of the production through various enhanced oil recovery processes such as water and CO2 floodings previously coded in UTCOMP. Benefiting from the higher time scales of solution variations due to the Geomchanics module, we lowered the frequency of calling this computationally expensive module. Also, we reduced the order of the finite element shape functions from quadratic to linear, which majorly mitigated the high computational cost of our Geomechanics studies while we almost maintained the solution accuracy. To validate our implementation, we investigated a primary oil production case and compared the results from UTCOMP with those from two other simulators: 1) CMG software program using different coupling methods; and 2) another pre-validated in-house reservoir simulator, GPAS. Moreover, due to the lack of real field data, we validated our solutions for the enhanced oil recovery problems by comparing them with those from GPAS coupled with Geomechanics. We observed a minor discrepancy between the solutions at very early times which originates from the different structures in these two reservoir simulators, IMPEC in UTCOMP and fully implicit in GPAS.

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