Deep coalbed methane (CBM) resources are abundant and represent a critical component of future energy supply and carbon reduction strategies. However, deep coal seams are characterized by well-developed cleat systems and high Poisson’s ratios, rendering the mechanisms of hydraulic fracture initiation, propagation, and complex fracture network development insufficiently understood. In this study, deep coal rock at a burial depth of 2700 m is investigated. A finite element–based hydraulic fracturing model incorporating complex face-cleat and end-cleat networks is established by explicitly representing cleat geometry, mechanical properties, fluid leak-off behavior, and hydraulic loading conditions. Using this model, the effects of cleat inclination angle, horizontal stress difference, and displacement on fracture evolution are systematically analyzed. The results indicate that when face cleats are orthogonal to the maximum horizontal principal stress, fractures preferentially penetrate cleats and propagate along the maximum stress direction. In contrast, when face cleats form acute angles with the maximum horizontal stress, pronounced branching fractures develop along both face and end cleats, with propagation increasingly dominated by face cleats as the angle decreases. Increasing horizontal stress difference suppresses fracture branching, leading to simpler fracture networks but greater total fracture length and maximum fracture width. Moreover, under identical injection pressures, the equal-pressure fracture length increases, indicating enhanced fracture propagation capacity. With increasing displacement, fracture networks evolve from simple to complex patterns, accompanied by accelerated propagation and enlarged fracture widths; however, excessive displacement intensifies fluid leak-off, ultimately reducing the equal-pressure fracture length.

CO₂ flooding is essential for enhancing oil recovery in low-permeability reservoirs; however, the large viscosity contrast between CO₂ and crude oil leads to severe gas channeling and low sweep efficiency. In this study, a binary composite system was constructed with a gas-soluble nonionic surfactant (OXO1312) as the foaming core and nano-SiO₂ as the Pickering stabilizer. The solubility of the surfactants in scCO₂ was evaluated at 60 °C and 20 MPa using a variable-volume apparatus, the foam performance was assessed by the Waring Blender method, and the foam morphology was observed by optical microscopy. The nonionic surfactants exhibited markedly higher scCO₂ solubilities (>2 wt%) than the anionic surfactants (<1 wt%), following a clear carbon-chain-length window effect. OXO1312, combining high CO₂-philicity with an appropriate EO number, was selected as the optimal foaming agent. The addition of 1.5 wt% nano-SiO₂ increased the drainage half-life of the OXO1312 system by 84% through pronounced Pickering stabilization. The binary system remained stable below 50 °C under moderate salinity, whereas the half-life declined sharply above 70 °C. These findings provide a theoretical basis for the formulation design of CO₂ foam flooding systems for CCUS-EOR.