Abstract: Using microseismic analysis to identify and quantify the hydraulic fracture interaction in the Earth formation. Identification of the interaction is based on the magnitude of the events and therefore independent of the location uncertainty. Quantification of the interaction is location based.

Abstract: Refracted energy travel time can help to derive anisotropic parameters in a target layer. These anisotropic parameters allow us to both explore for new reservoirs and to understand stress and fracturing in existing reservoirs. This information can be used to i) detect oil reservoirs, ii) spot naturally fractured, hence high production zones, iii) detect dominant natural stress directions, iv) better place horizontal wells to optimize production, v) monitoring man made fractures or induced directional stress changes. The method is demonstrated using synthetic and real data.

Abstract: Methods for fracture characterization of unconventional formations are provided. Synthetic seismic fracture responses can be generated based on the derived fracture parameters. The synthetic seismic fracture responses may then be used to derive optimum seismic data acquisition geometry for fracture characterization. These methods of determining the seismic data acquisition geometry are advantageous over conventional methods in that these methods are more reliable and cheaper than existing empirical methods, particularly as applied to fractured unconventional formations. Moreover, these methods allow fracture parameters to be derived from limited but common well log data. Certain embodiments additionally contemplate determining the presence of gas filled fractures. These characterizations and evaluations of unconventional formations are useful for, among other things, determining optimal producing intervals and optimal drilling locations. These methods can eliminate the use of costly image logs and core data.

Abstract: A method of event location to avoid first break picking when signals are small or the ambient noise level is high is described. In this method traveltime associated with the maximum amplitude phases (for any mode of wave) are identified and picked from one or more sensors in an array. Difference between the arrival times are then calculated. A grid search (or optimization) techniques are then employed to search for the event location to match the observed time differences.

Abstract: Refracted energy travel time can help to derive anisotropic parameters in a target layer. These anisotropic parameters allow us to both explore for new reservoirs and to understand stress and fracturing in existing reservoirs. This information can be used to i) detect oil reservoirs, ii) spot naturally fractured, hence high production zones, iii) detect dominant natural stress directions, iv) better place horizontal wells to optimize production, v) monitoring man made fractures or induced directional stress changes. The method is demonstrated using synthetic and real data.

Abstract: A method is described for identifying anisotropic regions in unconventional hydrocarbon reservoirs, such as in shale formations. Anisotropy can be indicative of a zone of fracturing, which may represent a “sweet spot” for drilling a productive well. Seismic amplitude data from receivers is recorded along two orthogonal lines radiating from a seismic source. After time-migration, the equations for each orthogonal direction may be summed to obtain values for A and (Biso+0.5*Bani) which are independent of azimuth angle. Since Biso is normally constant or slow varying over a shale formation, anisotropic regions may be identified by looking for anomalous values of (Biso+0.5*Bani).

Abstract: Methods for fracture characterization of unconventional formations are provided. Synthetic seismic fracture responses can be generated based on the derived fracture parameters. The synthetic seismic fracture responses may then be used to derive optimum seismic data acquisition geometry for fracture characterization. These methods of determining the seismic data acquisition geometry are advantageous over conventional methods in that these methods are more reliable and cheaper than existing empirical methods, particularly as applied to fractured unconventional formations. Moreover, these methods allow fracture parameters to be derived from limited but common well log data. Certain embodiments additionally contemplate determining the presence of gas filled fractures. These characterizations and evaluations of unconventional formations are useful for, among other things, determining optimal producing intervals and optimal drilling locations. These methods can eliminate the use of costly image logs and core data.