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CO2 injection into a saline aquifer crossed by a tectonic fault is studiedwith coupled fluid mechanics - geomechanics modeling. The simulation approachis based on coupling of the MUFITS reservoir simulator and the FLAC3Dmechanical simulator via an in-house API (i.e., an algorithm for data transferbetween simulators). MUFITS simulates the non-isothermal multiphase flow of CO2and brine in rock formation accounting for phase transitions and thermaleffects. The modeling workflow is sequential, so that hydrodynamicalsimulations are carried out at a certain time interval, after which pressure,temperature, and density distributions are passed to FLAC3D, which calculatesthe equilibrium mechanical state. Computed deformations and stresses areutilized to update the porosity and permeability fields for the subsequenthydrodynamic modeling. In particular, we focus on the tectonic fault and itsbehavior during CO2 injection. We distinguish the damage zone and core insidethe fault and derive the closure relations for their permeability alterationanalytically. The coupled approach developed here is applied to simulate CO2injection into synthetic and realistic reservoir models. For the former one, westudy the effect of formation depth and presence of the tectonic stresses atthe initial mechanical state, while for the latter, we consider differentinjection modes (bottomhole pressure). In each numerical experiment, wedescribe the evolution of the fault permeability due to the slip along itsplane and the development of plastic deformations leading to the loss ofreservoir integrity and CO2 leakage. Sensitivity analysis of the coupled modelto realistic values of input parameters to assess the fault stability iscarried out.

CO2 storage in deep saline aquifers: evaluation of geomechanical risks using integrated modeling workflow