Inova Gmbh

Ion Geophysical Corporation

Schlumberger Technology Corporation

Schlumberger Technology Corpoation

Services Petroliers Schlumberger

Geoquest Systems B.v.

Robert Ian Bloor

Gary Arthur Sitton

J MacDonald Smith

Ian Moore

David Nichols

Marvin Decker

Michel Schonewille

William Goodell Sanger

Sribharath Kainkaryam

Marvin Glen Michael Decker

Systems, computer readable, and methods concern receiving seismic data representing a subsurface volume. The method also includes determining, for the seismic data, analysis coordinates as a function of time. One or more of the analysis coordinates may vary in position over time. The method includes performing at least one of an interpolation or regularization process on the seismic data based at least partially on the analysis coordinates. The method also includes outputting a result of the at least one of the interpolation or regularization process.

Interpolation of seismic data with time variant locations

A method can include selecting a location associated with a seismic survey geometry; selecting a trace for the location where the trace is selected from one of a plurality of different types of traces that include real data traces, interpolated data traces and model data traces; generating a multiple model based at least in part on the selected trace; and adjusting seismic data based at least in part on the multiple model.

Attenuation of multiple reflections

Systems, methods, and computer-readable media for determining a velocity model. The method includes receiving a first velocity model having a first symmetry approximation of a media of a subterranean domain, receiving seismic data representing a subterranean formation, and determining, by operation of a processor, a second velocity model having a second symmetry approximation of the media, the second symmetry approximation being less symmetric than the first symmetry approximation. The second velocity model is determined based on an estimate of residual moveout as a function of azimuth and one or more differentials that relate one or more changes in residual moveout as a function of azimuth to one or more orthorhombic parameters. The method also including migrating the seismic data using the second velocity model.

Performing tomography to build orthorhombic models

Methods, apparatuses, and systems are disclosed for datuming multi-component seismic data. In one example of such a method, a plurality of seismic traces are accessed, the plurality of seismic traces including data representative of amplitude and spatial gradient samples of a seismic wavefield at a plurality of recording locations in a medium. Using a computer-based processing unit, a wavefield propagation from the plurality of recording locations through a medium is initialized, using the amplitude and spatial gradient samples of the seismic wavefield. Seismic traces are generated that correspond to the propagated wavefield at defined locations within the medium.

Method and apparatus for multi-component datuming

Seismic acquisition systems are disclosed that allow contemporaneous seismic sources to be separated from a composite signal comprising two or more constituent seismic sources. In some embodiments, a representation of the composite signal may be developed that includes a noise contribution of undesired signals present in the composite signal. Additionally, an operator, referred to herein as an 'annihilator', may be developed such that it may be conditioned and inverted to minimize undesired noise contributions in the composite signal. This inversion may assist in recovering the constituent seismic sources from the composite signal. Furthermore, in some embodiments, the accuracy with which the constituent source measurements are approximated may be increased by implementing them as random sweeps having a conventional length.

Seismic source separation

A method and apparatus for generating a seismic source signal are provided for generating energy in the form of a plurality of time sequence vibratory signals, the vibratory signals being partitioned as a function of time and/or frequency, wherein each of the plurality of signals comprises a distinguishing signature. The partitioned vibratory signals are emitted into a terrain of interest as seismic source signals for conducting a seismic survey.

Acquiring seismic vibrator signals having distinguishing signatures

A seismic system has a plurality of seismic sources. Each of the seismic sources includes a reaction mass movable with respect to a geological structure and includes an actuator moving the reaction mass. The movement of the reaction mass emits a source signal as seismic energy into the geological structure. In the system, each of the source signals is generated from a base vibratory signal segmented into a plurality of segments, where the base vibratory signal sweeps from an initial frequency to a final frequency. Each of the segments has a partition of sweep frequencies different from the other segments. Each of the source signals has a distinguishing arrangement of the segments different from the other source signals.

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Houston, TX, United States of America

Robert Ian Bloor