Abstract: A method for modeling a reservoir includes receiving vertical formation data describing geological formations in a vertical direction as a function of vertical depth, receiving near-wellbore horizontal formation data describing the geological formations in a horizontal or deviated direction near a wellbore up to a wellbore instrument range, correlating the vertical formation data with the near-wellbore horizontal formation data to create horizontally adjusted formation data to describe the geological formations in the vertical direction beyond the wellbore instrument range, along the horizontal or deviated direction, receiving hydraulic fracture geometry data that describes actual hydraulic fracture geometry, and limiting a described geometry of the geological formations to the actual hydraulic fracture geometry to provide an accurate estimation of usable reservoir.

Abstract: A method for modeling a reservoir includes receiving vertical formation data describing geological formations in a vertical direction as a function of vertical depth, receiving near-wellbore horizontal formation data describing the geological formations in a horizontal or deviated direction near a wellbore up to a wellbore instrument range, and correlating the vertical formation data with the near-wellbore horizontal formation data to create horizontally adjusted formation data to describe the geological formations in the vertical direction beyond the wellbore instrument range, along the horizontal or deviated direction.

Abstract: A procedure that integrates petrophysics and rock typing taken from vertical well measurements, 3D seismic elastic properties and seismic attributes, and geostatistical modeling to build a 3D reservoir model is provided. The 3D reservoir model may be directly incorporated into horizontal fracture model designs. The developed 3D reservoir model for a subsurface volume may be used in a fracture model to optimize fracturing designs and maximize well performance.

Abstract: A method for modeling a reservoir includes receiving vertical formation data describing geological formations in a vertical direction as a function of vertical depth, receiving near-wellbore horizontal formation data describing the geological formations in a horizontal or deviated direction near a wellbore up to a wellbore instrument range, correlating the vertical formation data with the near-wellbore horizontal formation data to create horizontally adjusted formation data to describe the geological formations in the vertical direction beyond the wellbore instrument range, along the horizontal or deviated direction, receiving hydraulic fracture geometry data that describes actual hydraulic fracture geometry, and limiting a described geometry of the geological formations to the actual hydraulic fracture geometry to provide an accurate estimation of usable reservoir.

Abstract: A procedure that integrates petrophysics and rock typing taken from vertical well measurements, 3D seismic elastic properties and seismic attributes, and geostatistical modeling to build a 3D reservoir model is provided. The 3D reservoir model may be directly incorporated into horizontal fracture model designs. The developed 3D reservoir model for a subsurface volume may be used in a fracture model to optimize fracturing designs and maximize well performance.

Abstract: A method for modeling a reservoir includes receiving vertical formation data describing geological formations in a vertical direction as a function of vertical depth, receiving near-wellbore horizontal formation data describing the geological formations in a horizontal or deviated direction near a wellbore up to a wellbore instrument range, and correlating the vertical formation data with the near-wellbore horizontal formation data to create horizontally adjusted formation data to describe the geological formations in the vertical direction beyond the wellbore instrument range, along the horizontal or deviated direction.

Abstract: Permeability prediction systems and methods using quadratic discriminant analysis are presented. At least one disclosed method embodiment includes: acquiring formation property measurements at a plurality of positions along at least one borehole in a study area; identifying clusters in a plurality of points representing the formation property measurements at the plurality of postions; and determining a system permeability value for each cluster. Quadratic Discriminant Analysis (“QDA”) is used to associate one the clusters with each position along the one or more boreholes, thereby determining a system permeability prediction for each position. The total system permeability can then be predicted by aggregating the system permeability predictions.

Abstract: Permeability prediction systems and methods using quadratic discriminant analysis are presented. At least one disclosed method embodiment includes: acquiring formation property measurements at a plurality of positions along at least one borehole in a study area; identifying clusters in a plurality of points representing the formation property measurements at the plurality of postions; and determining a system permeability value for each cluster. Quadratic Discriminant Analysis (“QDA”) is used to associate one the clusters with each position along the one or more boreholes, thereby determining a system permeability prediction for each position. The total system permeability can then be predicted by aggregating the system permeability predictions.

Abstract: Methods for determining whether to perform a stimulation treatment on a subterranean zone are disclosed. Process zone stress (“PZS”), indicative of a production potential of the subterranean zone, is determined, and a determination is made as to whether the PZS exceeds a preselected value. A PZS exceeding the preselected value may indicate a poor production potential, and a stimulation treatment of the subterranean zone may be avoided. As a result, a substantial cost saving associated with the avoided stimulation treatment may be realized.

Abstract: Methods for determining whether to perform a stimulation treatment on a subterranean zone are disclosed. Process zone stress (“PZS”), indicative of a production potential of the subterranean zone, is determined, and a determination is made as to whether the PZS exceeds a preselected value. A PZS exceeding the preselected value may indicate a poor production potential, and a stimulation treatment of the subterranean zone may be avoided. As a result, a substantial cost saving associated with the avoided stimulation treatment may be realized.