A workflow is proposed that estimates hydraulic fracture half-lengths by relating microseismic response to seismic data. The benefit of the multi-seismic based estimates is the data driven ability to produce estimates of fracture geometry beyond a rectangular or box model of stimulated rock volume. Understanding the shape of the fracture geometry well help constrain the multi-variate production simulation problem. To establish workflow fidelity seismic estimates are compared to reservoir engineering simulation estimates of fracture geometry and found to show a reasonable correlation.
Note: This paper was accepted into the Technical Program but was not presented at IMAGE 2021 in Denver, Colorado.