Investigation of fully coupled fracture propagation and oil–water two-phase flow mechanisms in fracturing flooding

Low-permeability reservoirs present significant challenges for conventional development methods, with fracturing flooding emerging as a promising technique to enhance both injectivity and production. This study presents an integrated approach to simulate fracture propagation and fluid distribution during fracturing flooding in these challenging formations. The methodology combines ABAQUS extended finite element method for fully coupled simulation of fracture dynamics with a dual-porosity dual-permeability model for multiphase flow characterization. These complementary methods are integrated through correlation charts, overcoming the limitations of single-platform simulation. Results demonstrate that fractures primarily extend along maximum horizontal stress direction, transitioning from elliptical to circular morphology with continued injection. Permeability influences pressure distribution patterns, while stress difference determines fracture propagation asymmetry. Production simulations over two years reveal that smaller stress differences produce more uniform displacement effects and higher cumulative oil recovery. This integrated framework provides a practical approach for optimizing fracturing flooding operations while offering insight into the interaction between geomechanical fracturing and multiphase flow dynamics in low-permeability reservoirs.