Geophysical prospecting may be achieved using borehole seismic data and processing velocity seismic profiles using downward continuation to simulate the seismic source being at the depth of the borehole receivers. Such methods may involve collecting seismic data for a subterranean formation with at least one borehole receiver; grouping the seismic data into a one common receiver gather corresponding to each borehole receiver; performing a downward continuation on at least one of the common receiver gathers to produce corresponding downward continued common receiver gathers; performing a normal moveout analysis on at least one of the downward continued common receiver gathers to produce corresponding semblance velocity spectra; and analyzing at least one of the semblance velocity spectra for a zone of interest in the subterranean formation.

Geophysical prospecting may be achieved using borehole seismic data and processing velocity seismic profiles using downward continuation to simulate the seismic source being at the depth of the borehole receivers. Such methods may involve collecting seismic data for a subterranean formation with at least one borehole receiver; grouping the seismic data into a one common receiver gather corresponding to each borehole receiver; performing a downward continuation on at least one of the common receiver gathers to produce corresponding downward continued common receiver gathers; performing a normal moveout analysis on at least one of the downward continued common receiver gathers to produce corresponding semblance velocity spectra; and analyzing at least one of the semblance velocity spectra for a zone of interest in the subterranean formation.

A data acquisition program, which includes core, image log, microseismic, DAS, DTS, and pressure data, is described. This program can be used in conjunction with a variety of techniques to accurately monitor and conduct well stimulation.

A data acquisition program, which includes core, image log, microseismic, DAS, DTS, and pressure data, is described. This program can be used in conjunction with a variety of techniques to accurately monitor and conduct well stimulation.

An embodiment of a method of stimulating an earth formation includes: disposing a stimulation device at a borehole in an earth formation, the earth formation having been stimulated by an initial stimulation operation; subsequent to the stimulation operation, performing a probe operation configured to cause movement of existing fractures in the formation; and measuring microseismic events occurring in the formation by one or more seismic receivers. The method further includes: identifying one or more target zones in the formation based on the measuring, the one or more target zones exhibiting a reduced micro seismicity relative to another zone in the formation; and designing a re-stimulation operation configured to stimulate the one or more target zones to increase hydrocarbon production from the formation.

An embodiment of a method of stimulating an earth formation includes: disposing a stimulation device at a borehole in an earth formation, the earth formation having been stimulated by an initial stimulation operation; subsequent to the stimulation operation, performing a probe operation configured to cause movement of existing fractures in the formation; and measuring microseismic events occurring in the formation by one or more seismic receivers. The method further includes: identifying one or more target zones in the formation based on the measuring, the one or more target zones exhibiting a reduced micro seismicity relative to another zone in the formation; and designing a re-stimulation operation configured to stimulate the one or more target zones to increase hydrocarbon production from the formation.

Method for characterizing subterranean formation is described. One method involves simulating a poroelastic pressure response of known fracture geometry utilizing a geomechanical model to generate a simulated poroelastic pressure response. Compiling a database of simulated poroelastic pressure responses. Measuring a poroelastic pressure response of the subterranean formation during a hydraulic fracturing operation to generate a measured poroelastic pressure response. Identifying a closest simulated poroelastic pressure response in the library of simulated poroelastic pressure response. Estimating a geometrical parameter of a fracture or fractures in the subterranean formation based on the closest simulated poroelastic pressure response.

A method may include providing a sensor in a first wellbore segment, providing a sensor in a second wellbore segment, observing upgoing acoustic waves or downgoing acoustic waves with the sensors, and separating the upgoing acoustic waves and/or the downgoing acoustic waves from a total wavefield. The first wellbore segment and the second wellbore segment may be separated by a distance. At least one of the wellbore segments may be non-vertical and/or the first wellbore segment may not be parallel to the second wellbore segment. The first wellbore segment may be part of a first set of wellbores and the second wellbore segment may be part of a second set of wellbores. The separated upgoing and downgoing acoustic waves may be used to generate deghosted data.

A method may include providing a sensor in a first wellbore segment, providing a sensor in a second wellbore segment, observing upgoing acoustic waves or downgoing acoustic waves with the sensors, and separating the upgoing acoustic waves and/or the downgoing acoustic waves from a total wavefield. The first wellbore segment and the second wellbore segment may be separated by a distance. At least one of the wellbore segments may be non-vertical and/or the first wellbore segment may not be parallel to the second wellbore segment. The first wellbore segment may be part of a first set of wellbores and the second wellbore segment may be part of a second set of wellbores. The separated upgoing and downgoing acoustic waves may be used to generate deghosted data.

A system and a method for producing an anisotropic velocity model. Vertical seismic profile (VSP) data is obtained for a geological area. At least two stiffness coefficients in a fourth-rank elasticity stiffness tensor are calculated based on p-wave and s-wave velocities determined using the VSP data. Microseismic profile data for the geological area is obtained and all remaining unknown stiffness coefficients in the fourth-rank elasticity stiffness tensor are calculated using the microseismic profile data.