Economic development of tight gas reservoirs often rely on hydraulic fracturing to stimulate production. Passive microseismic mapping of these hydraulic fractures is a quickly growing technology to map fracture geometry and complexities created during these stimulations. Reliable microseismic locations depend on an accurate velocity model. In this study we examine velocities obtained from Vertical Seismic Profile (VSP) data, perforation shots from an adjacent well, and microseismic data to determine an anisotropic velocity model for improved microseismic hypocentral locations. The observed anisotropy is consistent with an effective media representation of the geological reservoir structure.


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