Determining stimulated reservoir volume from passive seismic monitoring
View Patent ↗A method for determining a stimulated rock volume includes determining a position of a plurality of seismic events from seismic signals recorded in response to pumping fracturing fluid into a formation penetrated by a wellbore. The signals generated by recording output of a plurality of seismic receivers disposed proximate a volume of the Earth's subsurface to be evaluated. A source mechanism of each seismic event is determined and is used to determine a fracture volume and orientation of a fracture associated with each seismic event. A volume of each fracture, beginning with fractures closest to a wellbore in which the fracturing fluid was pumped is subtracted from a total volume of proppant pumped with the fracture fluid until all proppant volume is associated with fractures. A stimulated rock volume is determined from the total volume of fractures associated with the volume of proppant pumped.
1. A method for determining a stimulated rock volume from microseismic signals, comprising:
determining a position of each of a plurality of seismic events from seismic signals recorded in response to pumping fracturing fluid into a formation penetrated by a wellbore, the signals generated by recording output of a plurality of seismic receivers disposed proximate a volume of the Earth's subsurface to be evaluated, the signals being electrical or optical and representing seismic amplitude;
determining a source mechanism of each of the plurality of seismic events;
determining a fracture volume and orientation of a fracture associated with each of the plurality of seismic events from each source mechanism;
successively subtracting a volume of each fracture, beginning with fractures closest to a wellbore in which the fracturing fluid was pumped from a total volume of a proppant pumped with the fracture fluid and continuing such subtraction for successively radially more distant fractures until the total volume of the proppant is associated with fractures; and
determining a stimulated rock volume from the total volume of fractures associated with the volume of proppant pumped.
2. The method of claim 1 further comprising determining a propped fracture length from fractures associated with proppant most distant from the wellbore.
3. The method of claim 1 further comprising constraining positions of the determined fractures by subtracting an uncertainty in vertical position based on uncertainty of a checkshot conducted at a known depth in a wellbore.
4. The method of claim 1 wherein the source mechanism comprises at least one of source moment, dip of the fracture, strike of the fracture, rake of the microseismic events, volumetric change resulting from the fractures and compensated linear vector dipole.
5. The method of claim 1 wherein the determining position of seismic events from the recorded signals comprises determining positions of visible seismic events and determining positions of invisible seismic events having a same source mechanism as the visible seismic events by matched filtering the determined invisible events by a filter corresponding to the visible seismic events.
6. The method of claim 5 wherein the visible seismic events are determined by amplitude threshold detection in the recorded signals.
7. The method of claim 1 further comprising assigning a volume of one half an amount of proppant calculated to otherwise fit within fractures having orientation larger than about 45 degrees from a main fracture orientation to account for tortuosity and greater resistance to proppant containing fluid flow around corners.