Abstract: A method for minimizing the risk of induced seismicity from injection of fluids into a naturally fractured reservoir uses a meshless particle-based simulation to quantify the heterogeneity in energy storage within the reservoir. In particular, this methodology creates an equivalent fracture model from data on the natural fracture density, regional stress, pore pressure and elastic properties of the reservoir, in which points in the reservoir have a fracture length and fracture orientation. A meshless particle-based method is then employed to simulate the geomechanical interaction between regional stress and natural fractures to estimate the stress anisotropy and strain (e.g., differential stress and shear strain). The induced seismicity potential is then calculated at points in the reservoir based on the estimated stress anisotropy and strain. A zone for injection of fluids into the reservoir can be selected by identifying a large area of the reservoir having low induced seismicity potential.

Abstract: A method for minimizing the risk of induced seismicity from injection of fluids into a naturally fractured reservoir uses a meshless particle-based simulation to quantify the heterogeneity in energy storage within the reservoir. In particular, this methodology creates an equivalent fracture model from data on the natural fracture density, regional stress, pore pressure and elastic properties of the reservoir, in which points in the reservoir have a fracture length and fracture orientation. A meshless particle-based method is then employed to simulate the geomechanical interaction between regional stress and natural fractures to estimate the stress anisotropy and strain (e.g., differential stress and shear strain). The induced seismicity potential is then calculated at points in the reservoir based on the estimated stress anisotropy and strain. A zone for injection of fluids into the reservoir can be selected by identifying a large area of the reservoir having low induced seismicity potential.