| Summary: | Microseismic moment tensor (MT) contains important information on the reservoir and fracturing mechanisms. Difficulties arise when attempting to retrieve complete MT with conventional amplitude inversion methods if only one well is available. With the full-waveform approach, near-field information and non-direct waves (i.e. refracted/reflected waves) help stabilize the inversion and retrieve complete MT from the single-well dataset. However, for events which are at far field from the monitoring well, a multiple-well dataset is required. In this study, we perform the inversion with a dual-array dataset from a hydrofracture stimulation in the Barnett shale. Determining source mechanisms from the inverted MTs requires the use of a source model, which in this paper is the tensile earthquake model. The tensile model could describe the source more adequately and predict non-DC components. The source information derived includes the fault plane solution (FPS), slip direction, Vp/Vs ratio in the focal area and seismic moment. The primary challenge of extracting source parameters from MT is to distinguish the fracture plane from auxiliary plane. We analyze the microseismicity using geomechanics and use the insights gained from geomechanical analysis to determine the fracture plane. Furthermore, we investigate the significance of non-DC components by F-test. We also study the influence of velocity model errors, event mislocations and data noise using synthetic data. The results of source mechanism analysis are presented for the events with good signal-to-noise ratios (SNRs). Some events have fracture planes with similar orientations to natural fractures delineated by core analysis, suggesting reactivation of natural fractures. Other events occur as predominantly tensile events along the unperturbed maximum horizontal principal stress (SHmax) direction, indicating an opening mode failure on hydraulic fractures. Microseismic source mechanisms not only reveal important information about fracturing mechanisms, but also allow fracture characterization away from the wellbore, providing critical constraints for understanding fractured reservoirs.
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