Westerngeco L.l.p.

Other

Schlumberger Technology Corporation

Reece Innovation Centre Limited

Westergeco L.l.c.

Geco Technology B.v.

Ralf Ferber

Christophe Zaroli

Andreas W Laake

Stephen Pickering

Robert Montgomery Laws

Dirk-Jan Van Manen

Ali Ozbek

Claudio Bagaini

Massimiliano Vassallo

Robert Hughes Jones

Alan Gaither Teague

Debra M Dishberger

Claudio Strobbia

Simone Stuart-Cole

Robin Walker

Paal Kristiansen

Kamil Zerouk

Franz Kirchheimer

Reza Tamadoni

Lee West

Luke Griffiths

Jonathan (Boff) Anthony Anderson

Stephen Morice

Ahmet Kemal &Ouml;zdemir

Rebecca Sills

Ali &Ouml;zbek

James Martin

Robin Charles Walker

Larry Velasco

Jonathan Anthony Anderson

Stephen Charles Pickering

A method for inspecting a conduit comprising the steps of: emitting an outgoing signal into the conduit to establish an acoustic plane wave within the conduit; and detecting a reflected outgoing signal from the conduit, wherein the outgoing signal is arranged such that low frequency components contribute to more of the outgoing signal, from a time perspective, than high frequency components.

System for monitoring and/or surveying conduits

A shot interval between activations of at least one frequency-controllable survey source is determined, where the shot interval is determined based on an expected frequency of an output of the at least one frequency-controllable survey source. The at least one frequency-controllable survey source is activated using the determined first shot interval.

Determining an interval between activations of at least one survey source

Described herein are implementations of various technologies for a method for seismic data processing. The method may receive seismic data for a region of interest. The seismic data may be acquired in a seismic survey. The method may receive a summation that is based on a particle motion velocity component of a seismic wavefield in the vertical direction and the pressure component of the seismic wavefield. The method may predict an upgoing pressure component of the seismic wavefield for the region of interest. The method may compare the predicted upgoing pressure component to the received seismic data that corresponds to the received summation. The method may update the predicted upgoing pressure component based on the comparison. The method may use the updated upgoing pressure component in hydrocarbon exploration or production for the region of interest.

Seismic data processing

A method to perform a marine seismic survey includes obtaining marine seismic data corresponding to a subterranean formation under a water surface. The marine seismic data is generated from an underwater seismic sensor that is subject to an interference effect. The method further includes generating, by a computer processor and using a deconvolution operation, corrected marine seismic data based at least in part on the marine seismic data to compensate for the interference effect, and generating, by the computer processor, a marine seismic survey result based at least in part on the corrected marine seismic data.

Processing collected survey data

A method for processing seismic data. The method includes receiving the seismic data acquired by at least two receivers that are disposed at different depths. The method may then time-align the seismic data, collect a portion of the time-aligned seismic data into a gather and sum the collected time-aligned seismic data in the gather. After summing the collected time-aligned seismic data in the gather, the method may widen a spectrum of the summed seismic data and generate an image of subsurface formations in the earth based on the widened spectrum.

Attenuating sea-surface ghost wave effects in seismic 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 computer implemented technique for use in seismic data interpretation and, more particularly, with respect to near-surface geological structures, includes a computer-implemented method, including: jointly interpreting a plurality of complementary data sets describing different attributes of a near-surface geologic structure; and ascertaining a near-surface geomorphology from the joint interpretation. In another aspect, the technique includes a program storage medium encoded with instructions that, when executed, perform such a method. In yet another aspect, the method includes a computing apparatus programmed to perform such a method.

Joint interpretation of Rayleigh waves and remote sensing for near-surface geology

The technologies described herein include systems and methods for reducing noise in seismic data. More specifically, implementations may determine an amount of over-sampling for a frequency range of seismic data. Then, implementations may determine frequency bands based on the over-sampling. For each frequency band minimum-noise seismograms may be selected from consecutively occurring blocks of seismograms, and the remaining seismograms within each block may be discarded. The minimum-noise seismograms may then be used to reconstruct the discarded seismograms. The reconstructed seismograms may contain less noise than the original seismograms and, consequently, the seismic data may contain less noise.

Attenuating noise in seismic data

A method and apparatus for correcting an input seismic trace. The method includes receiving the input seismic trace and creating a t by Q gather using the input seismic trace, where t represents traveltime, Q represents absorption parameter, and the t by Q gather has traveltime as the vertical axis and a ratio of t and Q as the horizontal axis. The ratio of t and Q is referred to as R. The method further includes applying an interpolation algorithm to the t by Q gather to derive a corrected input seismic trace.

Method for correcting input seismic traces from dissipative effects

A method and apparatus for a method for generating an estimated value of absorption parameter Q(t). In one embodiment, the method includes receiving an input seismic trace, applying a time variant Fourier transform to the input seismic trace to generate a time variant amplitude spectrum of the input seismic trace, dividing the natural logarithm of the time variant amplitude spectrum by &#x2212;&#x3c0;f, and performing a power series approximation to the result with an index starting from one to generate an estimated value of R(t). R(t) is a ratio between traveltime t and the absorption parameter Q(t). The method further includes dividing t by R(t) to generate the estimated value of the absorption parameter Q(t).

Method for estimating absorption parameter Q(T)

A method for processing seismic data. The method includes receiving the seismic data acquired at one or more receivers due to one or more marine vibroseis sources that emit one or more vibroseis sweeps. The method then applies a receiver motion correction algorithm to the received seismic data to generate receiver motion corrected seismic data. After generating the receiver motion corrected seismic data, the method transforms the receiver motion corrected seismic data into a temporal Fourier domain to generate seismic data as a function of frequency. The method then reconstructs the transformed seismic data as a function of frequency to correct for one or more motions of the one or more marine vibroseis sources. After reconstructing the transformed seismic data, the method transforms the reconstructed seismic data to the time domain. The method then generates a seismic image of a subsurface of the Earth based on the transformed reconstructed seismic data.

Marine vibroseis motion correction

A method of processing seismic data including convolving at least first and second seismic data traces or respective portions of at least first and second seismic data traces to forma composite trace. The travel time of an event may then be determined in the composite trace. This provides an improved method compared to the prior art technique of picking the travel time of an event individually in each one of a number of seismic data traces and averaging the individual picked travel times.

Processing seismic data

The present invention relates to producing a quality control measure for use during data acquisition and/or data processing of, preferably, seismic data. While or after obtaining the data, a surface consistent decomposition of the data is performed. From the surface consistent decomposition, one may compute a decomposed logarithmic spectra, and from the decomposed logarithmic spectra, one may compute one or more residua. An error attribute based on the one or more residua can be formulated, analyzed, and output. The error attribute can be used as a quality control measure or the analysis result can be used to produce a quality control measure.

Seismic data acquisition and processing quality control

A method for interpolating irregularly sampled seismic data, including receiving seismic data acquired at irregularly spaced seismic sensors in a survey area, defining a plurality of regularly spaced locations in the survey area, forming an annular ring around one of the plurality of regularly spaced locations, and interpolating the seismic data inside the annular ring to estimate seismic data that would have been acquired at the one of the plurality of regularly spaced locations.

Annular-sum transform of irregularly sampled seismic data

Various methods for simulating up-going pressure wavefield data. In one implementation, a processing apparatus may receive pressure data from pressure sensors that may be installed on a first and second streamer of an over/under streamer pair. The processing apparatus may also receive velocity data from velocity sensors that may be installed on the second streamer of the over/under streamer pair. Using the pressure and velocity data obtained from the sensors installed on each streamer, the processing apparatus may simulate the pressure and velocity data that would have been obtained by a streamer in a calm sea at a depth equal to the vertical distance between the first and second streamers. The simulated pressure and velocity data may then be combined to estimate the up-going pressure wavefield data.

Growing community of inventors

Horsham, United Kingdom

Ralf Ferber