Westerngeco L.l.p.

Seismic Apparition Gmbh

Apparition Geoservices Gmbh

Other

Services Petroliers Schlumberger

Geoquest Systems B.v.

Westerngeco Seismic Holdings Limited

Dirk-Jan Van Manen

Massimiliano Vassallo

Johan O A Robertsson

Johan Robertsson

Kurt Eggenberger

Robert Montgomery Laws

Johan Olof Anders Robertsson

David Fraser Halliday

Fredrik Andersson

Ali Ozbek

Andrew Curtis

Ali Özbek

Ahmet Kemal Ozdemir

Philippe Caprioli

Susanne Rentsch-Smith

Aslaug Strommen Melbo

Ralf Ferber

Philip A F Christie

Remco Muijs

Anthony D Curtis

Johan Olaf Anders Robertsson

Susanne Rentsch

Aslaug Strommen Melboe

Stephen Paul Bracken

James E Rickett

A simultaneous sources seismic acquisition method is described that introduces notch diversity to improve separating the unknown contributions of one or more sources from a commonly acquired set of wavefield signals while still allowing for optimal reconstruction properties in certain diamond-shaped regions. In particular, notch diversity is obtained by heteroscale encoding.

Method for seismic acquisition and processing

A method for separating the unknown contributions of two or more sources from a commonly acquired set of wavefield signals representing a wavefield where the contributions from different sources are both encoded by means of the principles of signal apparition and as well as by means of different source encoding techniques.

Simultaneous source acquisition and separation method

Methods are described for separating the unknown contributions of two or more sources from a commonly acquired aliased wave field signals including the determination of models with reduced support in the frequency-wavenumber domain which reconstruct the wave fields of independently-activated sources after a coordinate-transform of the acquired wave field data and/or in a coordinate-transformed domain.

De-aliased source separation method

A method is described for removing the surface ghost from and/or separating wave field data and/or for estimating redatuming operators of the wave field data by effective use of a transform that that relies on the non-uniform distribution of distances with respect to a reference surface or of tuned-source radiation directions of sources and or the non-uniform distribution of receivers with respect to a reference surface to partition or map the wave field from at least two different cones in the transformed domain and using the contribution of sources and or receivers inside at least one of the at least two different cones to estimate a first wave field of interest, a second separated or ghost wave field and/or redatuming operator.

Method for deghosting and redatuming operator estimation

Methods are described for separating the unknown contributions of two or more sources from a commonly acquired set of wavefield signals representing a wavefield where the sources traverse general, related activation lines or grids and are synchronously activated while varying at least one parameter between the sources.

Simultaneous source acquisition and separation on general related sampling grids

A technique includes receiving seismic data indicative of measurements acquired by seismic sensors. The measurements are associated with a measurement noise. The technique includes estimating at least one characteristic of the measurement noise and deghosting the seismic data based at least in part on the estimated characteristic(s) of the measurement noise.

Deghosting and interpolating seismic data

Methods and systems for survey operations are provided. In some embodiments, crossline measurement data measured by at least one survey receiver is received. Based at least in part on a characteristic of the crossline measurement data, an option from among a plurality of candidate options is selected, where the selected option is for use in an action relating to survey of a target structure.

Using crossline measurement data for an action relating to survey of a target structure

The technologies described herein include systems and methods for performing a first seismic survey and performing a second seismic survey after a predetermined amount of time has lapsed between the first seismic survey and the second seismic survey. The shot times and the shot positions of the second seismic survey may be substantially the same as the shot times and the shot positions of the first seismic survey. After performing the seismic surveys, seismic data generated by the first seismic survey may be processed to generate a first image, and seismic data generated by the second seismic survey may be processed to generate a second image. After generating the first and second images, a difference between the first image and the second image may be computed to generate a time lapse difference image.

Seismic data acquisition and source-side derivatives generation and application

A method for removing noise from a three-dimensional representation of seismic data. The method includes receiving seismic data acquired in a seismic survey. The method may organize the acquired seismic data into a three-dimensional representation of the acquired seismic data. The method may then remove a noise from the three-dimensional representation of the acquired seismic data based on at least one criterion.

Noise removal from 3D seismic representation

A technique includes receiving sensor acquired data, which includes pressure data representative of at least one pressure measurement of a wavefield and particle motion data representative of at least one particle motion measurement of the wavefield. The technique includes filtering the pressure data and the particle motion data with a plurality of directional filters to provide a plurality of filtered datasets. The filtered datasets are associated with different directional ranges. The technique includes estimating an angle of incidence for at least one of the directional ranges based at least in part on at least one of the filtered datasets; and processing the acquired data to determine at least one of an upgoing component of the wavefield and a downgoing component of the wavefield based at least in part on the at least one estimated angle of incidence.

Wavefield deghosting

A technique includes processing seismic data indicative of samples of at least one measured seismic signal in a processor-based machine to, in an iterative process, determine basis functions, which represent a constructed seismic signal. The technique includes in each iteration of the iterative process, selecting another basis function of the plurality of basis functions. The selecting includes based at least in part on the samples and a current version of the constructed seismic signal, determining a cost function; and interpreting the cost function based at least in part on a predicted energy distribution of the constructed seismic signal to select the basis function.

Matching pursuit-based apparatus and technique to construct a seismic signal using a predicted energy distribution

A technique includes obtaining multi-component seismic data acquired by two or more seismic sensors while in tow. The multi-component seismic data is indicative of a pressure wavefield and particle motion. The technique includes based on the data, determining at least one high order (i.e., second order or higher) spatial derivative of the pressure wavefield.

System and technique to determine high order derivatives from seismic sensor data

In response to at least one input criterion, one or more target positions in an acquisition domain are determined for processing of survey data, where the survey data is acquired by survey equipment in the acquisition domain having a first set of dimensions, and where the processing of the survey data is to be performed in a processing domain having a second set of dimensions different from the first set of dimensions.

Determining one or more target positions in an acquisition domain for processing survey data

A technique includes receiving data, which are indicative of measurements acquired by seismic sensors of a seismic wavefield. The seismic wavefield is formed from a combination of an upgoing wavefield and a downgoing wavefield. The technique includes providing a statistical estimator, which relates the upgoing wavefield to a linear combination of the measurements and a reconstruction error. The technique includes determining the upgoing wavefield based on the statistical estimator. The determination includes substantially minimizing a variance of the reconstruction error.

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Redhill, United Kingdom

Dirk-Jan Van Manen