Westerngeco L.l.p.

Schlumberger Technology Corporation

Other

Westerneco L.l.c.

Claudio Bagaini

Daniele Boiero

Robert Montgomery Laws

Ian Moore

Emmanuel Coste

John Quigley

Nicolas Goujon

Nicolae Moldoveanu

Julian Edward Kragh

Ralf Ferber

Kambiz Iranpour

Jon-Fredrik Hopperstad

Massimiliano Vassallo

Pascal Guillaume Edme

Everhard Johan Muijzert

Einar Holst

Martin Laycock

Artem Kashubin

Glen-Allan Tite

Pieter Leonard Vermeer

Colin Readman

Timothy James Dean

Colin George Anderson

Robert Vincent

Timothy Dean

Amr Misbah

Phillip J Bilsby

A method includes acquiring seismic data of a region that utilizes multiple seismic energy sources and seismic energy receivers where the seismic data include blended seismic data for a number of emissions from a corresponding number of the multiple seismic energy sources; determining spatially distributed coherent noise properties for the region using the blended seismic data; via the spatially distributed coherent noise properties, modeling coherent noise as at least two coherent noise models for at least two of the emissions from a corresponding at least two of the multiple seismic energy sources; via the coherent noise models, attenuating coherent noise in a portion of the blended seismic data to generate coherent noise attenuated blended seismic data; deblending the coherent noise attenuated blended seismic data to generate deblended seismic data; and rendering an image of at least a portion of the region to a display using the deblended seismic data.

Noise attenuation of multiple source seismic data

A method for seismic processing includes receiving seismic data representing a subsurface volume. The seismic data includes a first horizontal component and a second horizontal component. The first and second horizontal components are rotated such that the first horizontal component is substantially aligned with a source of a seismic wavefield and the second horizontal component is substantially transverse to the source of the seismic wavefield. A splitting intensity is determined at a boundary of the subsurface volume using the first and second horizontal components after the first and second horizontal components are rotated. An anisotropic parameter is determined for a portion of the subsurface volume as a function of time using the splitting intensity.

Horizon-based splitting intensity inversion for anisotropic characterization of a target volume

A method can include receiving information associated with an interface between a first medium and a second medium where the information includes sensor data; based on at least a portion of the information, estimating wave properties that include elastic properties, depth-dependent properties and horizontal slowness; and, based on the estimated wave properties, calculating an orientation of a sensor utilized to acquire at least a portion of the sensor data.

Seismic sensor orientation

A seismic data recording unit. The seismic data recording unit may include a housing and retractable arms coupled to the housing. The seismic data recording unit may include a respective seismic sensor coupled proximate the end of a retractable arm. The retractable arm may move from a position on or proximate the housing to a position away from the housing.

Seismic data recording units

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

Methods and systems for marine survey acquisition are disclosed. In one embodiment, a method is provided that may deploy a marine seismic spread that includes a first seismic source, a second seismic source and a streamer with a receiver. The second source may be disposed at a distance from the first seismic source in an inline direction. The distance may be selected to produce one or more pairs of shot points during a seismic survey. The shot points within a pair may be disposed within a range that is used to calculate a pressure source gradient between the shot points within the pair. The method may shoot the first seismic source and the second seismic source substantially simultaneously. The method may record seismic data associated with shooting the first seismic source and the second seismic source. The method may calculate the pressure source gradient for respective pairs of shot points.

Methods and systems for marine survey acquisition

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

Methods and apparatuses for obtaining and/or processing slip sweep seismic survey data. The methods compute harmonic weight ratios using two types of data: 1) direct survey data where a harmonic sweep does not overlap with the fundamental component of responses of Earth interior and 2) another set of data representative of fundamental component of responses of Earth interior where the harmonic sweep does overlap with the fundamental component of responses of Earth interior. The set of data representative fundamental component of responses of Earth interior can be extracted from ground force measurements or a different sweep. The harmonic weight ratios using ground force measurements at overlapped frequencies may be calibrated with one or more harmonic weight ratios at non-overlapped frequencies.

Vibroseis acquisition method

A seismic sensor device includes an elongated housing for placement at least partially into an earth surface. A plurality of particle motion sensors are contained in the elongated housing to measure translational data in a first direction, where plural pairs of the particle motion sensors are spaced apart along a second, different direction along a longitudinal axis of the elongated housing. A communication interface communicates the measured translational data to a computer system configured to compute a gradient based on respective differences of the measured translational data of the corresponding plural pairs of the particle motion sensors, and compute one or more of rotation data and divergence data using the gradient.

Computing a gradient based on differences of plural pairs of particle motion sensors

A seismic land vibrator, comprising a baseplate comprising a substantially flat, rigid member; at least one driven member that is connected with the baseplate and extends in a direction that is substantially perpendicular to baseplate; a rotation sensor that is coupled to the baseplate and adapted to provide a signal that is indicative of rotational movement of at least a portion of the baseplate.

Seismic vibrator device and method with rotation sensor

An embodiment of the invention includes combining pseudorandom sweeps with an independent, or nearly independent, survey acquisition technique. Targeted design of pseudorandom sweeps can direct the majority of cross-correlation noise to lie outside key time-lags of the record (i.e., windows of interest). Embodiments of the invention are described herein.

Sweep sequence determination for overlapping sweeps

A technique is designed for conducting a seismic survey. The technique utilizes a plurality of vibrator arrays employed to conduct a seismic survey utilizing low frequency and high frequency vibrators in each vibrator array. The plurality of vibrator arrays continuously sweeps low frequency signals via low frequency vibrators. While sweeping low frequency signals, high-frequency vibrators emit high-frequency signals in an alternating pattern between vibrator arrays to enhance the seismic survey.

Enhancing low frequency content in marine simultaneous vibroseis acquisition

A method and related apparatus are described for generating acoustic signals for use in a vibratory seismic survey, including at least two different sweep signals for the control of at least two different types of vibrators; and matching the phases of the different sweep signals at a transition frequency from one sweep signal to another.

Seismic vibratory acquisition method and apparatus

A seismic source array includes a first source and a second source. The first source has a first spectral output and the second source has a second spectral output different than the first spectral output. The first source has a first total volume different than a second total volume of the second source.

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Cottenham, United Kingdom

Claudio Bagaini