Abstract: A method of modeling a subsurface area of a seabed using fewer seismic sensors than a seismic sensors that generate sufficient data to permit a desired model of the subsurface area. Seismic datasets are received from the fewer seismic sensors. The fewer seismic sensors are located at points defined in relation to the seabed. Boundary conditions of a seismic wavefield at a fluid-solid interface between the seabed and water above the seabed are identified. An estimation, from the seismic datasets and the boundary conditions, is made of one or more virtual datasets. Each of the virtual datasets includes corresponding estimated data for additional points defined in relation to the seabed. The points and the additional points, combined, are sufficient to permit the desired model of the subsurface area. A subsurface model of the subsurface area is generated by modeling the subsurface area using the seismic datasets and the virtual datasets.

Abstract: A method for transforming seismic images includes receiving input data. The input data includes an original upward-downward diffusion (UDD) seismic image and an original multi-dimensional deconvolution (MDD) seismic image. The method also includes training a generator and a discriminator based upon the input data to produce a trained generator and a trained discriminator.

Abstract: The disclosed method includes simultaneously transmitting, using a first seismic source and a second seismic source: a first signal from the first seismic source; and a second signal from the second seismic source. The method also includes: determining, based on detecting the simultaneously transmitted first signal and second signal, wave number data; and designating, based on the wave number data, a position of the first seismic source relative to the second seismic source. The method also includes: determining, based on the position of the first seismic source relative to the second seismic source, optimal phase modulation of the simultaneously transmitted first signal and second signal that enable deterministic separation of the simultaneously transmitted first signal and second signal in the plane wave domain; and using the optimal phase modulation to resolve or separate wavefields included in the simultaneously transmitted first signal and second signal in the plane wave domain.

Abstract: Disclosed is a method comprising: receiving captured seismic data and generating first velocity and first pressure data therefrom; transforming, from a first data domain to a second data domain, the first velocity and first pressure data and thereby generate second velocity and second pressure data; mapping wavenumber gather data from the second data domain to a third data domain; determining envelope ratio scaling data and threshold value data using the second velocity and second pressure data; generating, threshold envelope data using a thresholding operator associated with the threshold value data; using coefficient data associated with the threshold envelope data to estimate vertical component data; transforming, from the third data domain to the first data domain, the vertical component data to generate temporal-spatial data; and generating, based on the temporal-spatial data, noise component data comprised in the captured seismic data.

Abstract: A method for generating a model for a water velocity in an ocean includes receiving input data. The method also includes determining a time-averaged water velocity as a function of depth based upon the input data. The method also includes determining a threshold depth based upon the time-averaged water velocity. The method also includes determining a polynomial based upon the threshold depth. The method also includes determining the water velocity in the ocean as a function of time and depth based upon the polynomial. The method also includes generating or updating the model based upon the water velocity as the function of time and depth.

Abstract: Systems and methods are provided for performing multidimensional deconvolution. An exemplary method includes: receiving, using at least one processor, a first data associated with waves propagating in a seismic structure; selecting, using the at least one processor, a first transform to be applied to the first data; determining, using the least one processor, whether the first transform is a sparsity or rank revealing transform to optimize sparsity or rank minimization; if the first transform is the sparsity or rank transform, applying, using the at least one processor, the first transform to the first data to produce a second data; calculating, using the at least one processor and the second data, at least one Green's function associated with the first data; and predicting, using the at least one processor and the at least one Green's function, material properties throughout the seismic structure to facilitate exploratory and/or production operations.

Abstract: A method can include receiving seismic survey data of a subsurface environment from a seismic survey utilizing water bed receivers, where each of the receivers includes a clock; assessing one or more clock calibration criteria; based on the assessing, selecting a clock drift processor for processing at least a portion of the seismic survey data from a plurality of different clock drift processors; using at least the clock drift processor, performing a simultaneous inversion for values of model-based parameters; and, using at least a portion of the values, generating processed seismic survey data that represents one or more geological interfaces in the subsurface environment.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.