Publications

The DRT field, located west of Stavanger at the southern end of the Norwegian sector is characterized by a dome-shaped caprock structure with 66 faults and a constant friction coefficient of 0.6. A laboratory study of 8 sandstone cores showed average friction angles ranging from 32.4° to 37.0° and cohesion values between 10.1MPa and 10.7 MPa. This study identifies CCUS scenarios with a CO2 EOR scheme for utilization and converting to injection (CTI) of wells for CO2 storage focusing on rock stability and failure mechanism. The model is filtered so that the active blocks are 126,535 grids with a total of 13 wells (4 injectors and 9 producers), representing a field with an Original Oil In Place (OOIP) of 137.171 MMSTB, a Recovery Factor (RF) of 44.29%, an initial pressure of 329.6 bar, a porosity 0.225, a connate water saturation (Swc) of 0.203, permeability (X&Y) of 1799 mD, and permeability Z of 493 mD. Geomechanical property analysis, including an Unconfined Compressive Strength (UCS) test and reservoir simulation, showed strike-slips (SHmax>Sv>SHmin), a medium Poisson’s Ratio classification (0.28), a Young’s Modulus and Poisson’s Ratio relationship suggesting less brittle sedimentary rock, and UCS values classified as low (0.15 MPa). Redevelopment under the CO2 -EOR scheme increased RF to more than 52.6% over 4 years without inducing rock failure. Furthermore, the next scheme (2030-2070) involved CCS with a CO2 injection rate of 3.93 MMSCFD and a total of 36.47 Mt of CO2 injected (11 CTI wells), was simulated for 100 years to demonstrate long-term viability. This study confirms the feasibility of converting production wells to injection wells for CO2 storage while ensuring rock stability. This study uniquely integrates geomechanical properties into the design of CO2 injection wells, offering novel insights for long-term CCS strategies.