Landmark Graphics Corporation

Halliburton Energy Services, Inc.

Landmark Graphics Corporation, a Halliburton Company

Stewart Arthur Levin

Paul F Rodney

Daniel J Grygier

David Earle Johnston

Michael John Eberhard

Apparatus, systems, and methods may operate to receive radiated energy as scattered energy after the radiated energy interacts with a geologic formation, wherein the scattered energy is received at a sub-surface multi-channel sensor array that operates to transform the scattered energy into received signals, and wherein the radiated energy is provided by a sub-surface source of elastic energy; and to identify discontinuous features in the geologic formation by interferometric comparison of the received signals as elastic signals and/or electromagnetic signals among some sensors in the sensor array, or by time-reversal propagation of the received signals as elastic and/or electromagnetic signals in a numeric model of a volume of the geologic formation. Additional apparatus, systems, and methods are disclosed.

Fracture characterization by interferometric drillbit imaging, time reversal imaging of fractures using drill bit seismics, and monitoring of fracture generation via time reversed acoustics and electroseismics

A system and method for locating subsurface diffractors. The method operates on two-dimensional (2-D) seismic data that includes one or more 2-D seismic lines. The 2-D seismic data may be preprocessed to enhance diffracted energy. For each hypothetical diffractor location in a set of hypothetical diffractor locations, the method involves analyzing at least a subset of the seismic traces of the one or more 2-D seismic lines, in order to compute a value indicating an extent to which those seismic traces contain diffraction arrivals consistent with the hypothetical diffractor location. The method may further involve generating, storing and displaying an image (or map) based on the computed values. The image may illustrate areas of high, intermediate and low diffraction, and may be used to assess the formation.

Analyzing borehole seismic data to locate subsurface diffractors

Analyzing 2-D surface and/or borehole seismic data to locate subsurface diffractors

Systems and methods for monitoring time-dependant subsurface changes from imperfectly repeated data measurements.

Systems and methods for monitoring time-dependent subsurface changes

Systems and methods for enhancing the resolution of a seismic data image displayed on a face of a sampling probe. The enhanced image represents a maximum resolution of at least a portion of the seismic data image. The seismic data image is enhanced by extracting seismic data that are perpendicular to a reflection surface that is closest to a center of the sampling probe and positioning the extracted seismic data in a visible planar face of the sampling probe.

Systems and methods for enhancing a seismic data image

A method for analyzing seismic data from a formation. The method may first receive two-dimensional (2-D) seismic data of a formation comprising a number of individual seismic lines acquired over an exploration area and having a large interline spacing. The 2-D seismic data may then be preprocessed to enhance diffracted energy. For each respective hypothetical diffractor location, the method may then search for coherent diffraction arrivals on nearby 2-D seismic lines consistent with the respective hypothetical diffractor location. The method may then store information regarding identified diffractor locations. The method may then create a map based on the identified diffractor locations, wherein the map illustrates areas of high diffraction. The map may then be displayed on a display, wherein the map is useable to assess the formation.

Performing 3-D scatterer imaging from 2-D seismic data

Methods, systems, and computer readable media are provided for interactively determining optimum deghosting parameter values for suppressing ghost reflections. Seismic data are obtained from various hydrophone/geophone receiver locations. Energy traces are generated which include measures of the deghosting parameter values from the seismic data obtained from each of the hydrophone/geophone receiver locations. The energy traces are displayed. A set of seed values is provided by the user. In response to receiving the user seed values, deghosting parameter values are picked based on the energy traces. The picked deghosting parameter values are displayed. A user then interactively edits and/or smooths the picks to obtain optimum deghosting parameter values. The optimum deghosting parameter values are utilized for suppressing ghost reflections in the seismic data.

Methods, systems, and computer readable media for interactively determining parameters for ocean-bottom hydrophone/geophone receiver combination deghosting

System and method for analyzing seismic data from a formation. Stacked seismic data are provided, including a plurality of stack traces, e.g., by collecting seismic data from source and receiver locations and stacking the collected seismic data to produce the stacked seismic data. 3-dimensional (3-D) prestack traces are generated from the plurality of stack traces, e.g., by performing inverse moveout of stack traces, e.g., in a specified neighborhood, at common-depth-points, e.g., by inverse normal moveout, ray tracing, spike synthesis, etc. The inverse moveout corrected traces are convolved to compute predicted multiples which are useable in analyzing the formation. The multiples may be adaptively subtracted from the stacked seismic data, or optionally, from prestack data, to generate processed seismic data useable in analyzing the formation, e.g., for petroleum production potential. Dip moveout (DMO) corrected seismic data may be used, where DMO velocities are adjusted by dividing by cosine of the dip angle.

Growing community of inventors

Centennial, CO, United States of America

Stewart Arthur Levin