System for predicting induced seismicity potential resulting from injection of fluids in naturally fractured reservoirs
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.
1. A method for minimizing the risk of induced seismicity resulting from injection of fluids into a naturally fractured reservoir, said method comprising:
creating an equivalent fracture model from data on the natural fracture density, regional stress, pore pressure and elastic properties of the reservoir, said equivalent fracture model having an array of points modeling an estimated fracture length and fracture orientation at corresponding points in the reservoir;
simulating the geomechanical interaction between regional stress and natural fractures in the reservoir by a meshless particle-based method using the equivalent fracture model as an input to estimate the stress anisotropy and strain at points in the reservoir;
calculating induced seismicity potential at points in the reservoir based at least in part on the estimated stress anisotropy and strain; and
minimizing the risk of induced seismicity by selecting a site for injection of fluids into the reservoir by identifying a region of the reservoir having induced seismicity potential below a predetermined value.
2. The method of claim 1 wherein the stress anisotropy data comprises the local maximum principal stress direction at points in the reservoir.
3. The method of claim 1 wherein the strain data comprises shear strain at points in the reservoir.
4. The method of claim 1 further comprising the step of validating the estimated stress anisotropy and strain data against actual seismic data for the reservoir.
5. A method for minimizing the risk of induced seismicity resulting from injection of fluids into a naturally fractured reservoir, said method comprising:
creating an equivalent fracture model from data on the natural fracture density, regional stress, pore pressure and elastic properties of the reservoir, said equivalent fracture model having an array of points modeling an estimated fracture length and fracture orientation at corresponding points in the reservoir;
simulating the geomechanical interaction between regional stress and natural fractures in the reservoir by a meshless particle-based method using the equivalent fracture model as an input to estimate the differential stress and shear strain at points in the reservoir;
calculating induced seismicity potential at points in the reservoir based at least in part on the estimated differential stress and shear strain; and
minimizing the risk of induced seismicity by selecting a site for injection of fluids into the reservoir by identifying an area of the reservoir having induced seismicity potential below a predetermined value.
6. The method of claim 5 further comprising the step of validating the estimated differential stress and shear strain data against actual seismic data for the reservoir.