Westerngeco L.l.p.

Schlumberger Technology Corporation

Geco Technology B.v.

Ian Moore

William Henry Dragoset, Jr

Richard Bisley

Craig J Beasley

Claudio Bagaini

Clement Kostov

Paolo Terenghi

Robert Ian Bloor

Robin Fletcher

Clara Castellanos Lopez

Bartosz Szydlik

Antoun Henri

William Goodell Sanger

David Yingst

William H Dragoset

Jr William H Dragoset

A method can include receiving data in a data domain where a first portion of the data domain includes a signal to noise ratio that exceeds a signal to noise ratio in a second portion of the data domain; generating a model; in a transform domain, based at least in part on the model, filtering at least a portion of the data in the second portion of the data domain; and, based at least in part on the filtering, outputting noise attenuated data for at least a portion of the data in the second portion of the data domain.

Noise attenuation via thresholding in a transform domain

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

A technique includes generating vibroseis sweeps for a vibroseis survey to produce seismic data acquired in response to seismic signals produced by the sweeps. The generation of the vibroseis sweeps including temporally arranging the sweeps into time-overlapping groups. The technique includes regulating a timing of the groups relative to each other based on a slip time. The technique also includes regulating a timing of the sweeps of each group such that consecutive sweep firings of each group are spaced apart by a time substantially less than the slip time.

Dithered slip sweep vibroseis acquisition system and technique

Data representing a first multiple is predicted, based on first survey data for a target structure, using a multidimensional model of a layer in which the first multiple occurs. Modified survey data is produced by performing a subtraction of the predicted data representing the first multiple from the first survey data. Based on the modified survey data, data representing a second multiple is predicted using the multidimensional model.

Predicting multiples in survey data

Various implementations described herein are directed to methods for processing seismic data including enhancing seismic data generated by a seismic sensor. The methods may include receiving seismic data that had been acquired using the seismic sensor. The seismic data may include one or more first seismic data elements related to a first seismic event. The methods may include generating summands of the seismic data as an inner product of multiple seismic data elements associated with the first seismic data elements and one or more second seismic data elements. The second seismic data elements may be different than the first seismic data elements. The methods may further include enhancing the seismic data by estimating outliers in the summands of the inner product and replacing the outliers with interpolated values.

Seismic data enhancement

A method and apparatus for predicting interbed multiples is described herein. Trace geometries may be generated for one or more desired shot-side traces, one or more desired receiver-side traces, and one or more desired interbed multiple generator traces, for a first target trace. A first set of reflections at the interbed multiple generator layer may be extracted from one or more recorded traces closest to the desired interbed multiple generator traces. A second set of reflections below the interbed multiple generator layer may be extracted from one or more recorded traces closest to the desired shot-side traces. A third set of reflections below the interbed multiple generator layer may be extracted from one or more recorded traces closest to the desired receiver-side traces. The interbed multiples for the first target trace may be estimated based on the first set, the second set, and the third set.

Interbed multiple prediction

Computing systems and methods for processing collected data are disclosed. In one embodiment, a method for iteratively separating a simultaneous-source dataset is provided, wherein the simultaneous-source dataset is used as an input dataset for a first iteration of simultaneous-source separation. The input dataset includes a plurality of shots that include data corresponding to a plurality of source activations. The method of iteratively separating the input dataset includes generating simulated simultaneous shots based on shots separated in the input dataset; and forming an output dataset based on the separated simultaneous shots and the simultaneous-source dataset, wherein the output dataset is configured for use as the input dataset for the next iteration of separating the simultaneous-source dataset.

Methods and computing systems for processing data

A technique includes determining at least one parameter that characterizes a seismic survey in which multiple interfering seismic sources are fired and seismic sensors sense energy that is produced by the seismic sources. The determination of the parameter(s) includes optimizing the seismic survey for separation of the sensed energy according to the seismic sources.

Optimizing a seismic survey for source separation

A technique includes providing seismic data that is indicative of energy that is sensed in response to a first operation of at least one seismic source in a first seismic survey and a second operation of at least one seismic source in a second seismic survey. The technique includes processing the seismic data to determine a timing of the second operation relative to the first operation, and the technique includes based at least in part of the determined timing, processing the seismic data to generate a dataset, which is indicative of the sensed energy that is attributable to the first operation and is not attributable to the second operation.

Removing seismic interference using simultaneous or near simultaneous source separation

A method and apparatus for predicting a plurality of surface multiples for a plurality of traces in a record of seismic data. In one embodiment, the method includes providing a plurality of target traces at a nominal offset and a nominal azimuth; selecting a plurality of pairs of input traces, wherein the midpoints of the input traces in each pair are separated by half the nominal offset and the azimuth of a line connecting the midpoints of the input traces in each pair is equal to the nominal azimuth; convolving the selected pairs of input traces to generate a plurality of convolutions; and applying a three dimensional operator to the convolutions.

Fast 3-D surface multiple prediction

A method of processing seismic data including measurement data and their gradients to obtain gradients of move-out corrected data, comprising deriving gradients of the measurement data, deriving a first term comprising applying a move-out correction function to the measurement data; deriving a second term by applying the move-out correction function to the gradients and deriving gradients of move-out corrected data by adding the first term and the second term. The gradients of move-out corrected data are used to process physical properties of the earth's interior. The method may be used prior to any data processing algorithm which uses measurement gradient data in which move-out correction is applied prior to the algorithm, either because the algorithm makes a zero offset assumption or because it is beneficial for the algorithm to operate on move-out corrected data to reduce aliasing.

Move-out correction of seismic data

A method of processing seismic data including pressure data and pressure gradient data to obtain gradients of moveout corrected pressure data, comprising applying a move-out correction function to the pressure gradient data; and adding a correction term dependent on a moveout corrected time-derivative of the pressure data and a spatial derivative of the moveout correction function. The method may be used prior to any data processing algorithm which uses pressure gradient data in which moveout correction is applied prior to the algorithm, either because the algorithm makes a zero offset assumption or because it is beneficial for the algorithm to operate on moveout corrected data to reduce aliasing.

Moveout correction of seismic data

A method for spatially interpolating pressure values of seismic data uses known values of pressure and spatial derivatives of pressure at a plurality of irregularly spaced locations along the direction of interpolation. The interpolation preferably uses an interpolation operator calculated by assuming that an interpolated pressure value comprises a linear combination of the known pressure values at locations xand the spatial derivatives at locations X, with operator coefficients wand wrespectively, and calculating the coefficients by minimizing an error function.

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Highfields Caldecote, United Kingdom

Ian Moore