Westerngeco L.l.p.

Schlumberger Technology Corporation

Apparition Geoservices Gmbh

Seismic Apparition Gmbh

Eth Zurich

Johan Robertsson

Dirk-Jan Van Manen

Fredrik Andersson

Kurt Eggenberger

Arthur H Hartog

Everhard Johan Muyzert

Douglas E Miller

Andrew Curtis

Ed Kragh

Lasse Amundsen

Clement Kostov

Remco Muijs

Susanne Rentsch

Egil Holvik

Marc Serra Garcia

Tena Dubcek

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 for separating the unknown contributions of two or more sources from a commonly acquired set of wavefield signals based on varying parameters at the firing time, location and/or depth of the individual sources in a lateral 2D plane.

Method for seismic data acquisition and processing

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 seismic acquisition system includes a distributed optical sensor (having an optical fiber) and an interrogation subsystem configured to generate a light signal to emit into the optical fiber. The interrogation subsystem receives, from the distributed optical sensor, backscattered light responsive to the emitted light signal, wherein the backscattered light is affected by one or both of seismic signals reflected from a subterranean structure and noise. Output data corresponding to the backscattered light is provided to a processing subsystem to determine a characteristic of the subterranean structure.

Seismic acquisition system including a distributed sensor having an optical fiber

A technique includes obtaining seismic data acquired by at least one seismic sensor. The technique includes processing the seismic data to determine a value that is indicative of a three-dimensional directional propagation attribute of a seismic event based on the seismic data.

Determining directional propagation attributes of a seismic event

There is described a method of moveout or velocity analysis of seismic signals using the steps of obtaining such signalsfrom a plurality of receivers, identifying receiver functions within the acoustic signals, analyzing said receiver functions for velocity or moveout characteristics, using the result of said analyzing step to determine, properties of multiple layers of earth located below said 10 receivers. The analyses can involve the use of representation of the traveltime differences as approximated power series of slowness or horizontal distances. The method is the first to comprehensively deal with a multi-layered earth or velocity model.

Multi-component seismic data processing

Described is a finite-difference methodology for efficiently computing the response from a model subject to changes within sub-volumes with the sub-volume enclosed with an extrapolation surface within an injection boundary using Green's functions to update the injection boundary and transmitting an updated wavefield from the injection boundary back into the altered sub-volume to include higher order reflections from outside of the altered sub-space.

Method of evaluating the interaction between a wavefield and a solid body

A method is described for reducing multiples in marine seismic data using at least two sets of signals representing seismic energy reflected and/or refracted from an earth structure using a plurality of seismic receivers located in a body of water with the two sets differing in the traveltime of signals through the body of water, separating said signals into up- and down-going wavefields and combining the two sets to remove multiples.

Multiple attenuation method

A method is provided of processing multi-component seismic data acquired by emitting multi-component seismic energy at a source location and acquiring seismic data at a multi-component seismic receiver located at a greater depth than the source location. The seismic data are decomposed into up-going constituents and down-going constituents. A de-signature and de-multiple operator is calculated from the down-going constituents of the seismic data and from properties of the medium surrounding the receiver.

Method of and an apparatus for processing seismic data

A method of processing multi-component seismic data acquired at a receiver comprises determining a suitable decomposition scheme to use. This makes use of the existence of pairs of wavefield components that are uncoupled from one another. If there is no physical coupling between first and second wavefield components, the first and second components should not arrive at a receiver location at the same time. The method comprises decomposing a first portion, for example a test portion, of the seismic data into a plurality of wavefield components using an initial decomposition scheme. First and second wavefield components of the decomposed data that should be uncoupled from one another are then selected, and their product is determined. Since the first and second wavefield components of the decomposed data should be uncoupled from one another, their product should be zero or close to zero and a product that is significantly different from zero indicates that the decomposition scheme is inaccurate.

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Johan Robertsson