geomechanical modelling and cap-rock integrity of one of the southwest iranian giant carbonate oil field

Geomechanical modeling and simulation are introduced to accurately determine the combined effects of hydrocarbon production-injection scenarios and changes in rock properties due to geomechanical effects. pore pressure and stress states vary during production and injection steps. these variations considerably affect reservoir and cap-rock integrity, faults reactivation, formation compaction and uplifting, and wellbore stability. therefore, accurate pore pressure estimation is essential to maintain optimal conditions during injection and production operations. a series of data, including rock mechanical test data, well logs data, formation dynamic tester data, image logs data, leak-off tests (lots), drilling events, and regional geological studies were used in this work. in this study, a coupled geomechanical-fluid flow model was constructed to evaluate the cap-rock integrity during the injection-production scenario. the steps of the investigation are data audit, 1-d mechanical modeling (mems), 3d rock mechanical properties modeling, and 4d geomechanical simulation using a one-way coupling method. the results showed that throughout the production and injection scenario, the cap-rock was stable. since there is a long distance between mohr’s circle and the envelope, the cap-rock will not fail. due to the low permeability of the cap-rock, there is no connection between its pore spaces, which leads to ignoring the variation in stress state due to variations in reservoir pressure.

geomechanical modelling and cap-rock integrity of one of the southwest iranian giant carbonate oil field

geomechanical modeling and simulation are introduced to accurately determine the combined effects of hydrocarbon production-injection scenarios and changes in rock properties due to geomechanical effects. pore pressure and stress states vary during production and injection steps. these variations considerably affect reservoir and cap-rock integrity, faults reactivation, formation compaction and uplifting, and wellbore stability. therefore, accurate pore pressure estimation is essential to maintain optimal conditions during injection and production operations. a series of data, including rock mechanical test data, well logs data, formation dynamic tester data, image logs data, leak-off tests (lots), drilling events, and regional geological studies were used in this work. in this study, a coupled geomechanical-fluid flow model was constructed to evaluate the cap-rock integrity during the injection-production scenario. the steps of the investigation are data audit, 1-d mechanical modeling (mems), 3d rock mechanical properties modeling, and 4d geomechanical simulation using a one-way coupling method. the results showed that throughout the production and injection scenario, the cap-rock was stable. since there is a long distance between mohr’s circle and the envelope, the cap-rock will not fail. due to the low permeability of the cap-rock, there is no connection between its pore spaces, which leads to ignoring the variation in stress state due to variations in reservoir pressure.