Carbon dioxide (CO2) phase change fracturing technology generates a massive amount of energy through the phase change of injected fluid in a short period, where the fluid is extruded into the rock formation to drive the fracture propagation. Apart from the rock inertia effect during fracturing, fracture instability could be seen at the crack tip due to a significant phase changing fluid infiltration, which is often ignored in previous models. This work develops a multi-processes phase-field framework for CO2 phase change fracturing in rock formations. The phase changing effect for non-equilibrium multi-phase flow is coupled by modifying mass and energy conservation equations where the Vesovic model is utilized to accurately capture the transport properties of CO2 and the fluid infiltration. G-criterion correlated to the pore pressure gradient is introduced to describe rock strength degeneration caused by fluid infiltration, which destabilizes the fracture propagation. The model is validated against the experimental and theoretical results. Four different fracturing methods (water-based fracturing, CO2 fracturing, blasting fracturing, and CO2 phase change fracturing) are carefully analyzed, indicating that CO2 phase change fracturing generates multi-level branches while increasing the stimulated reservoir volume compared with water-based/CO2 fracturing. Different from blasting fracturing, the branching in CO2 phase change fracturing is mode II fracture caused by the fluid infiltration with weaker inertia effects rather than mode I dynamic fracture. The influences of different formation parameters on fracturing behaviors are further discussed, which provides theoretical guidance for engineering applications of CO2 phase change fracturing technology.
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