Abstract: A technique facilitates enhanced microseismic monitoring. The technique may be applied to source mechanism identification under, for example, ill-conditioned receiver coverage to enhance the resolvability for microseismic monitoring. The microseismic monitoring may be used in hydraulic fracturing monitoring, induced seismicity monitoring, CO2 injection monitoring, other injection monitoring, mining, and/or other techniques which cause microseismic events.

Abstract: A technique facilitates enhanced microseismic monitoring. In a variety of applications, the technique may be used to enhance the resolvability of moment tensor inversion for ill-conditioned seismic receiver coverage. As a result, microseismic monitoring technique enhances the capability for monitoring many types of naturally occurring and created seismic events. For example, the technique may be employed to enhance hydraulic fracturing monitoring, induced seismicity monitoring, CO2 injection monitoring, other injection monitoring, mining, and/or other techniques which cause microseismic events.

Abstract: Analysis of a seismic event, such as a microseismic event caused by hydraulic fracturing, comprises measuring seismic waves emitted by the event and converting the measurements into two values for magnitude of explosion or implosion and for magnitude of displacement discontinuity at a plane, together with two directions, a direction of a normal to the plane and a direction of displacement; where the two values and the two directions compose the moment tensor describing the seismic event. The measurements may be converted into the moment tensor and decomposed into the values and directions. The values and directions associated with several seismic events may be displayed concurrently on a graphic display as a graphic representation of multiple events, where each event may be depicted with magnitude of expansion or contraction represented by a volume and the plane represented as a laminar object.

Abstract: A technique facilitates enhanced microseismic monitoring. In a variety of applications, the technique may be used to enhance the resolvability of moment tensor inversion for ill-conditioned seismic receiver coverage. As a result, microseismic monitoring technique enhances the capability for monitoring many types of naturally occurring and created seismic events. For example, the technique may be employed to enhance hydraulic fracturing monitoring, induced seismicity monitoring, CO2 injection monitoring, other injection monitoring, mining, and/or other techniques which cause microseismic events.

Abstract: A technique facilitates enhanced microseismic monitoring. The technique may be applied to source mechanism identification under, for example, ill-conditioned receiver coverage to enhance the resolvability for microseismic monitoring. The microseismic monitoring may be used in hydraulic fracturing monitoring, induced seismicity monitoring, CO2 injection monitoring, other injection monitoring, mining, and/or other techniques which cause microseismic events.

Abstract: A technique facilitates performance of seismic profiling, such as three-dimensional vertical seismic profiling. A downhole acquisition system is provided with acoustic receivers designed to receive acoustic source signals. The firing of acoustic source signals is synchronized with the downhole acquisition system. Additionally, the firing of two or more acoustic source signals is controlled to provide simultaneous or nearly simultaneous timing of one acoustic source signal with respect to another acoustic source signal. A processing system is used to acquire and process a data stream of the initial shot and a data stream of the additional shot occurring simultaneously or nearly simultaneously.

Abstract: A technique includes receiving first seismic data acquired by one or more receivers in response to energy produced by one or more seismic sources interacting with a subsurface feature. The first seismic data is indicative of measured reflection coefficients for image points for the subsurface feature, the measured reflection coefficients are associated with incidence angles, and a range of the incidence angles varies with respect to an image point position. The technique includes processing the first seismic data in a machine to generate second data indicative of a normal incidence reflection coefficient for at least one of the image points not associated with a normal angle of incidence.

Abstract: Methods and systems for the detection and localization of microseismic events are proposed which operate in real-time. Hypocenters in three spatial dimensions are provided along with an estimate of the event origin time. Sensor positions may be distributed in 3D space, and are not confined to linear arrays in vertical wells. A location of the event is approximated and a grid search, based on the approximate location of the event, is used to derive a residual function over a finer sampling followed by a gradient search of the residual function to optimize the location of the event.

Abstract: Analysis of a seismic event, such as a microseismic event caused by hydraulic fracturing, comprises measuring seismic waves emitted by the event and converting the measurements into two values for magnitude of explosion or implosion and for magnitude of displacement discontinuity at a plane, together with two directions, a direction of a normal to the plane and a direction of displacement; where the two values and the two directions compose the moment tensor describing the seismic event. The measurements may be converted into the moment tensor and decomposed into the values and directions. The values and directions associated with several seismic events may be displayed concurrently on a graphic display as a graphic representation of multiple events, where each event may be depicted with magnitude of expansion or contraction represented by a volume and the plane represented as a laminar object.

Abstract: A technique includes receiving first seismic data acquired by one or more receivers in response to energy produced by one or more seismic sources interacting with a subsurface feature. The first seismic data is indicative of measured reflection coefficients for image points for the subsurface feature, the measured reflection coefficients are associated with incidence angles, and a range of the incidence angles varies with respect to an image point position. The technique includes processing the first seismic data in a machine to generate second data indicative of a normal incidence reflection coefficient for at least one of the image points not associated with a normal angle of incidence.