Abstract
A new fully coupled fluid flow and rock damage model is developed in order to simulate hydraulic fracture propagation in porous media. In the proposed model, damage evolution is driven by the maximum normal stress, and the rock permeability is varying as a function of the damage value. The nonlinear model is then linearized and solved monolithically using a Newton–Raphson method, and the numerical results are validated against some available experimental data. We study the effects of injection rate, fluid viscosity, and confining far-field stresses on the hydraulic fracture of rocks. The results indicate that the damage extend preferentially parallel to the direction of maximum applied stresses. If the in-situ stress field is isotropic, damage propagates almost uniformly in all directions, which is consistent with the uniform pressure contours around the injection point. The fluid pressure and damage area are both increasing with the increase of injection rate and fluid viscosity.
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