Abstract: A method for evaluating portions of a reservoir includes classifying producing reservoir portions in the reservoir into multiple classifications based on production data associated with the producing reservoir portions. Each classification corresponds to a range of the production data. The method further includes generating a correlation between the classifications of the producing reservoir portions to a petrophysical property and elastic property of the subterranean formation, generating, based on the correlation, a spatial distribution function of reservoir quality to represent predicted classifications as a function of physical locations in the reservoir, and evaluating, using the spatial distribution function, a physical location in the reservoir for reservoir quality.

Abstract: Methods, computing systems, and computer-readable media for processing seismic data. The method may include obtaining a model of a subterranean domain, and determining one or more synthetic waveforms for one or more events located in the subterranean domain, based at least partially on the model. The method may also include identifying, using a processor, one or more arrival waves in the one or more synthetic waveforms, wherein at least one of the one or more arrivals represents a mode-converted wave, and generating a processing chain for determining at least a location of an event in the subterranean domain based at least partially on the at least one mode-converted wave.

Abstract: A method for calibrating fracture networks. The method includes estimating an average fracture width of a fracture network using one or more of net fracturing pressure, Poisson's ratio, shear modulus, and fracture height; determining microseismic event envelope and base intensity data using a three-dimensional geomodel including microseismic event data; and determining hydraulic fracturing treatment (HFT) fracture intensity of post-hydraulic fracturing treatment (post-HFT) based on the average fracture width and HFT volume data. The method further includes calibrating the base intensity data to the HFT fracture intensity to obtain calibrated HFT fracture intensity, determining a proppant transportation and distribution scenario, and generating a dual porosity reservoir model based on the calibrated HFT fracture intensity and the proppant transportation and distribution scenario.

Abstract: Methods for in-situ reservoir investigation by borehole seismic methods are provided using receiver(s) and a downhole source. The downhole source may be a microseismic event, and may be located relative to the receiver(s) in any configuration. The downhole source may also be a controlled source that is positioned in a reverse vertical seismic profile (RVSP) geometry with respect to the receiver(s). The methods may involve locating the receiver(s) in a first well (which may have any orientation, including vertical or horizontal), and locating the source in a monitoring well (which may have any orientation, including vertical or horizontal), such that the source in the monitoring well is positioned at a greater depth in the formation than the receivers in the first well.

Abstract: A method for evaluating portions of a reservoir includes classifying producing reservoir portions in the reservoir into multiple classifications based on production data associated with the producing reservoir portions. Each classification corresponds to a range of the production data. The method further includes generating a correlation between the classifications of the producing reservoir portions to a petrophysical property and elastic property of the subterranean formation, generating, based on the correlation, a spatial distribution function of reservoir quality to represent predicted classifications as a function of physical locations in the reservoir, and evaluating, using the spatial distribution function, a physical location in the reservoir for reservoir quality.

Abstract: A microseismic monitoring system includes a seismic sensor positioned proximate to a wellbore traversing a formation; an orientation source producing an orientation shot; a hydraulic apparatus operationally connected with the formation to produce a fracture in the formation; a computer control system operationally connected with a database of known spectral attributes for event categories; and a computer readable medium that carries instructions executable by the computer control system that, when executed: receive data from the seismic sensor; select an event of interest from the data received; determine a spectral estimate of the selected event of interest; compare the determined spectral estimate of the selected event of interest to the known spectral estimates; and select from the data received by the seismic source the orientation shot for orientation of the seismic sensor.

Abstract: A technique includes determining a magnitude and frequency distribution of seismic events attributable to hydraulic fracturing in a given stage of a well. The technique includes based on the determined magnitude and frequency distribution, predicting at least one additional magnitude and frequency distribution of seismic events attributable to hydraulic fracturing in at least one additional stage of the well. The technique includes determining at least one seismic property of a system of hydraulic fractures based at least in part on the determined additional magnitude and frequency distributions.

Abstract: A method for calibrating fracture networks. The method includes estimating an average fracture width of a fracture network using one or more of net fracturing pressure, Poisson's ratio, shear modulus, and fracture height; determining microseismic event envelope and base intensity data using a three-dimensional geomodel including microseismic event data; and determining hydraulic fracturing treatment (HFT) fracture intensity of post-hydraulic fracturing treatment (post-HFT) based on the average fracture width and HFT volume data. The method further includes calibrating the base intensity data to the HFT fracture intensity to obtain calibrated HFT fracture intensity, determining a proppant transportation and distribution scenario, and generating a dual porosity reservoir model based on the calibrated HFT fracture intensity and the proppant transportation and distribution scenario.

Abstract: A microseismic monitoring system includes a seismic sensor positioned proximate to a wellbore traversing a formation; an orientation source producing an orientation shot; a hydraulic apparatus operationally connected with the formation to produce a fracture in the formation; a computer control system operationally connected with a database of known spectral attributes for event categories; and a computer readable medium that carries instructions executable by the computer control system that, when executed: receive data from the seismic sensor; select an event of interest from the data received; determine a spectral estimate of the selected event of interest; compare the determined spectral estimate of the selected event of interest to the known spectral estimates; and select from the data received by the seismic source the orientation shot for orientation of the seismic sensor.

Abstract: A technique includes generating a fracture network model to characterize a fracture system in a reservoir that is associated with a well. The generation of the model includes constraining the model based at least in part on identified naturally occurring fractures and microseismic measurements that were acquired during a fracturing operation that was conducted in the well.