Abstract: Deep shale gas development encounters extreme conditions, including high temperature, high geostress, and low permeability. Conventional hydraulic fracturing models often fail to accurately predict fracture propagation behavior because they typically neglect temperature–stress–seepage coupled effects and dynamic evolution of rock damage. To address these gaps, this study developed a mesoscopic thermo–hydro–mechanical coupled damage model for hot dry rocks. The model was validated against laboratory fracturing tests on deep shale sourced from the Sichuan Basin. In addition, hydraulic fracturing experiments were performed on shale at temperatures of 100–250℃ and confining pressures of 10–15 MPa to characterize fracture evolution. The results confirmed that the confining pressure determined whether fractures developed dominantly in horizontal or vertical orientations. Higher injection pressure produces a greater number of fractures. Raising the shale temperature increased the primary fracture extension length by approximately 20%. The proposed model elucidates how the temperature–damage interaction governs fracture morphology and provides theoretical guidance for designing efficient fracturing strategies in deep unconventional reservoirs.