Geological CO2 storage (GCS) is an effective method for reducing carbon emissions. However, as more such projects are deployed in the future, the associated risks of injection-induced fault reactivation require comprehensive assessment to ensure long-term and effective CO2 storage. This study presents an integrated assessment of the Illinois Basin–Decatur Project (IBDP) through a hybrid approach combining physics-based modeling and probabilistic forecasting. A coupled CO2-geomechanical model is developed to simulate CO2 injection at CCS1 well. The fault reactivation risks have been systematically evaluated by analyzing near-well and far-field fault slip tendency indices, spatiotemporal evolution of Coulomb failure stress (CFS), seismogenic index (Σ), and magnitude probability distributions. Results demonstrate that while permeability-controlled pore pressure diffusion dominates fault reactivation for both near-well and far-well faults, poroelastic stresses may induce localized fault slip and provide stabilization during shut-in periods. The reactivation state is significantly controlled by fault geometry. Higher initial injection rates substantially facilitate fault instability compared to constant or gradually increasing injection schemes. Based on field data, the applicability of the seismogenic index for carbon storage sites has been validated. The low seismogenic index (Σ ≈ −4) for this site confirms limited seismic potential, and the probability of seismic magnitude below 2.27 exceeds 50%. Probabilistic modeling further indicates that a controlled injection rate ramp-up preferentially induces seismicity with low magnitudes. The proposed hybrid forecasting approach enables a more comprehensive evaluation of fault reactivation risks at carbon storage sites.
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