Abstract
The microseismic method is a crucial technology for locating the fracture location during the hydraulic fracturing process. Conventionally, construction of velocity model using well logs, seismic data or calibration shots usually ignores the influence of fracturing process. In this paper, we study the influence of hydraulic fracturing on existing microseismic location methods. Based on the mass conservation, fluid seepage equation, fracture mechanics and critical pressure criterion, we simulate the 3D hydraulic fracturing process and obtain the microseismic events and pore pressure distribution. Then the velocity model is constructed using the Coates-Schoenberg method and fracture compliances. The 3D ray tracing method is applied to model the microseismic data and traditional location methods are applied to locate the events and analyze the inversion error. Simulation results show that, both source location and receiver location have influence on the inversion accuracy and the overall deviation increases with ray propagation distance in the fracturing domain.
Sign-in/Register to access full text options 
Talk to us
Join us for a 30 min session where you can share your feedback and ask us any queries you have
Schedule a callDisclaimer: All third-party content on this website/platform is and will remain the property of their respective owners and is provided on "as is" basis without any warranties, express or implied. Use of third-party content does not indicate any affiliation, sponsorship with or endorsement by them. Any references to third-party content is to identify the corresponding services and shall be considered fair use under The CopyrightLaw.
