Abstract This study addresses limitations of traditional temporary plugging models that neglect combined in-fracture and mouth-plugging effects. A USDFLD subroutine in ABAQUS simulates multi-stage plugging based on injection timing. Using the maximum circumferential stress criterion and cohesive zone model (CZM), a mechanical model for fracture propagation in tight reservoirs was established. Numerical simulations analyzed ground stress, fracture initiation, propagation, and morphology across plugging stages. Results show that temporary plugging significantly alters in-situ stress magnitude and direction, creating a weak stress point near the plugging location. The study clarifies formation conditions of main and branch fractures under real reservoir conditions. However, multi-stage plugging struggles to achieve effective results under high sHmax (7–8 MPa). By unraveling the mechanisms of complex fracture propagation, this work delivers actionable insights that directly inform the design and optimization of fracturing strategies in tight oil reservoirs.
Tao et al. (Wed,) studied this question.