Abstract: Techniques are disclosed for performing time-lapse monitor surveys with sparsely sampled monitor data sets. An accurate 3D representation (e.g., image) of a target area (e.g., a hydrocarbon bearing subsurface reservoir) is constructed (12) using the sparsely sampled monitor data set (11). The sparsely sampled monitor data set may be so limited that it alone is insufficient to generate an accurate 3D representation of the target area, but accuracy is enabled through use of certain external information (14). The external information may be one or more alternative predicted models (25) that are representative of different predictions regarding how the target area may change over a lapse of time. The alternative models may, for example, reflect differences in permeability of at least a portion of the target area. The sparsely sampled monitor data set may then be processed to determine (23) which of the alternative models is representative of the target area.

Abstract: Methods and systems for location and/or direction of a hypocenter. The methods may involve one or more of: a) computing a joint probability density function (PDF) which includes polarization PDF and onset time PDF or a time integral of product of detection transforms to estimate the location and/or direction of a hypocenter, where the polarization PDF is generated using a weighted average of differences between measured and computed polarizations; b) computing a time integral of product of modified detection transforms associated with onset times from received data in Coalescence Microsesimic Mapping where modified detection transform is defined as (?, fd(t)?1); c) resolving 180 degree ambiguities in polarization estimated according to Hodogram; d) using polynomial interpolation to tune the location of a hypocenter; and e) computing an integration time interval of 4-D (t,x,y,z) PDF or product of modified detection transform and the restriction on grid nodes.

Abstract: Methods, apparatuses, and systems are disclosed that reduce seismic noise. In one embodiment, a method of processing seismic data includes accessing seismic data representative of a plurality of seismic input traces acquired by one or more seismic sensors. The method also includes stacking the plurality of seismic input traces into a stacked trace. The method also includes generating, utilizing at least one processor unit, a function of similarity between at least two of the plurality of seismic input traces. The method also includes scaling at least one of the seismic input traces or the stacked trace with the function of similarity.

Abstract: Techniques are disclosed for performing time-lapse seismic monitor surveys with sparsely sampled monitor data sets. A more accurate 3D representation (e.g., image) of a target area (e.g., a hydrocarbon bearing subsurface reservoir) is constructed using the sparsely sampled monitor data set (11). The sparsely sampled monitor data set may be so limited that it alone is insufficient to generate an accurate 3D representation of the target area, but accuracy is achieved through use of certain external information (14). The external information may include information accurately identifying a shape of the seismic reflector(s) present in the target area. The shape may be predetermined from a fully sampled base survey, and used to enable an accurate 3D representation (12) of the target area to be later generated for a monitor survey using a sparsely sampled monitor data set.

Abstract: A computer-implemented method for processing a seismic trace of a subterranean region comprising: (a) deriving a seismic wavelet for a time-window of seismic trace; (b) generating a model for the subterranean region corresponding to that time-window comprising a plurality of seismic reflectors by comparing the seismic wavelet with the time-window of the seismic trace to identify locations for the seismic reflectors, wherein the locations of the seismic reflectors are subject to a separation constraint requiring neighboring seismic reflectors to be separated by at least a minimum separation threshold which is greater than a separation corresponding to a sampling interval for the seismic trace; (c) defining a model seismic wavelet having a model seismic wavelet amplitude spectrum with a frequency bandwidth which is greater than that of the seismic wavelet amplitude spectrum determined for the time-window of the seismic trace; and (d) generating a model of the time-window of the seismic trace for the subterranea

Abstract: Methods, software, and computer systems for 3D multiple prediction and removal are disclosed. The method includes determining a set of input diplets. The method includes, for one or more data diplets from the set of input diplets downward propagating the data diplet to model reflection of the data diplet at a location of at least one subsurface discontinuity and determining one or more predicted multiple diplets, based, at least in part on the data diplet and the modeled downward propagated and reflected diplet. The method includes comparing diplets in the set of input diplets with the one or more multiple diplets to determine a set of multiple diplets and a set of demultipled diplets.

Abstract: Systems, methods, and software can be used to update fracture planes based on microseismic data from a fracture treatment. In some aspects, a first fracture plane is updated based on a microseismic event in a microseismic data set associated with a fracture treatment. The first fracture plane is one of multiple previously-generated fracture planes. A second, different fracture plane of the previously-generated fracture planes is updated to account for information generated by updating the first fracture plane based on the microseismic event.

Abstract: Systems, methods, and software can be used to identify properties of fractures in a subterranean zone. In some aspects, a basic plane orientation is determined for each of a plurality of basic planes. The basic planes are defined by coplanar subsets of microseismic event data from a fracture treatment of a subterranean zone. The quantity of the basic plane orientations in each of a plurality of ranges is calculated. In some implementations, a histogram is displayed to indicate the quantity of basic plane orientations in each of the orientation ranges. A dominant fracture orientation is identified for the subterranean zone based on one or more of the identified quantities.

Abstract: Systems, methods and software can be used for analyzing microseismic data from a subterranean zone. In some aspects, a plurality of basic planes are each defined from a subset of the microseismic data and each have an orientation relative to a common axis. Clusters of orientations of the basic planes are identified adaptively based on the extent of variation in the orientations. The number of orientations associated with each of the clusters is then identified.

Abstract: Systems, methods and software can be used for analyzing microseismic data collected from a fracturing treatment of a subterranean zone. In some aspects, a plurality of basic planes are each defined from a subset of the microseismic data and each have an orientation relative to a common axis. Clusters of orientations of the basic planes previously identified adaptively based on the extent of variation in the orientations can be updated with new data. The number of orientations associated with each of the clusters is then identified.

Abstract: Systems, methods, and software can be used to identify fracture planes in a subterranean zone. In some aspects, data representing locations of microseismic events associated with a subterranean zone are received. Fracture plane parameters are calculated from the locations of the microseismic events. The fracture plane parameters are calculated based on a sum of weighted terms, and each of the weighted terms includes a weighting factor that decreases with a distance between at least one of the microseismic events and a fracture plane defined by the fracture plane parameters.

Abstract: Systems, methods, and software can be used to analyze microseismic data from a fracture treatment. In some aspects, stored data associate a fracture plane with a first plurality of microseismic events from a fracture treatment of a subterranean region. Additional stored data indicate an ordering of a second, different plurality of microseismic events from the fracture treatment. One of the second plurality of microseismic events is selected based on the ordering, and the fracture plane is updated based on the selected microseismic event.

Abstract: The invention is a method of calculating seismic time shifts ?{right arrow over (t)}(t), comprising: conducting a number (n) of three or more seismic surveys with large time differences such as months or years, producing a number (n) of three or more vintages of seismic data d1(t), d2(t), . . .

Abstract: Subsurface horizon assignment. At least some of the illustrative embodiments are methods including: obtaining, by a computer system, a seismic data volume; identifying, by the computer system, a plurality of patches in the seismic data volume, and the identifying thereby creating a patch volume; displaying, on a display device, at least a portion of the seismic data volume and the plurality of patches of the patch volume; and assigning a patch of the plurality of patches to a subsurface horizon of the seismic data volume.

Abstract: A method, an apparatus and a computer-readable medium for processing seismic data are provided. The method includes selecting well-imaged areas of a sediment-to-salt interface, and performing (1) a dual-flood RTM with prismatic waves to identify new areas of the sediment-to-salt interface, and (2) one or more RTM to identify other new areas of the sediment-to-salt interface or of a salt-to-sediment interface.

Abstract: Systems and methods create a velocity model for well time-depth conversion. In one implementation, a system optimizes a time-depth relationship applied to data points from a single well to estimate coefficients for a velocity function that models the data points. The system optimizes by reducing the influence of outlier data points, for example, by weighting each data point to decrease the influence of those far from the velocity function. The system also reduces the influence of top and bottom horizons of geological layers by applying data driven techniques that estimate the velocity function without undue dependence on the boundary conditions. The system can optimize estimation of a rate of increase in velocity to enable the velocity function to go through a data point on each top horizon. The system may also estimate each base horizon from trends in the data points and adjust the velocity function to go through a data point on each base horizon.

Abstract: A computer-implemented method includes providing a first velocity model obtained from a vertical seismic profile survey representative of an upper region of a subterranean formation. Wavefields from the first velocity model are datumed using wave equations to a datum line between the upper region and a target area beneath the upper region to obtain datumed wavefields. The method further includes obtaining interferometric common shot data and interferometric common midpoint data from the datumed wavefield using wave equations at the datum line. The first velocity model, the datumed wavefield, wavefield equations, and the interferometric common midpoint data are then used to generate a second velocity model representative of velocities in the target area.

Abstract: According to a preferred aspect of the instant invention, there is provided herein a system and method for imaging complex subsurface geologic structures such as salt dome flanks using VSP data. In the preferred arrangement, a receiver wave field will be downward continued through a salt flood model and a source wave field will be upward continued through a sediment flood model until they “meet” at the subsurface locations of the VSP receivers. The source and receiver wave fields will be cross correlated as an imaging condition at each depth interval.

Abstract: Methods for wavefield extrapolation using measurements of a wavefield quantity and a component of the gradient of the wavefield quantity are disclosed. The methods use “exact” representations of scattering reciprocity. The methods can yield “exact”, nonlinear, “true-amplitude” receiver wavefields that are beyond the receiver measurement boundary. Methods of evaluating/validating the extrapolated data are also disclosed. Some methods may also evaluate the accuracy of models for the areas where data are extrapolated or measured. These methods can be used in any industries involving imaging, such as geophysical/seismic exploration, bio-medical imaging, non-destructive remote sensing, acoustic space architecture, design and engineering.

Abstract: A method of modifying a seismic image of a subsurface region includes identifying a location within the seismic image that includes a distortion, indicating a structural change associated with the distortion, that is selected to at least partially correct for the distortion, identifying a region causing the distortion in which corrections to a velocity model corresponding to the seismic image are to be applied, performing an inversion for the region in accordance with the indicated structural change, updating the velocity model on the basis of the inversion, and producing a modified seismic image on the basis of the updated velocity model.

Abstract: Systems and methods for sonar image feature extraction, which fit a parameterized statistical model to sonar image data to extract features that describe image textures for follow-on pattern classification tasks. The systems and methods estimate the parameters of an assumed statistical model from the pixel values in the sonar images. The parameters of the distribution can then be used as features in a discriminant classifier to perform tasks such as texture segmentation or environmental characterization. The systems and methods divide a sonar image into separate overlapping cells. The ACF parameters of each cell are sequentially estimated using various methods. Based on the ACF parameters obtained, each cell is assigned a label via a pattern classification algorithm. The labeled image can be used in target recognition, environmental characterization and texture segmentation.

Abstract: A method for structural dip removal. The method includes converting a seismic volume to a depth domain, extracting seismic dips from the seismic volume in the depth domain along a borehole trajectory, analyzing a borehole using the seismic dips to obtain structural dip data, and in response to determining that the seismic dips and borehole dips obtained from borehole imagery are consistent, generating a three dimensional (“3D”) structural model using the structural dip data. The method further includes performing a structural restoration using the 3D structural model to obtain depositional geometry data, removing structural dip from the borehole imagery using the 3D structural model to obtain sedimentary dip data, and performing a stratigraphic interpretation using the depositional geometry data and the sedimentary dip data.

Abstract: Systems and methods create velocity models for a single well or for a set of wells. In one implementation, a system optimizes a time-depth relationship applied to data points from a single well to estimate coefficients for a linear-velocity-in-time function that models the data points. The system optimizes by reducing the influence of outlier data points, for example, by weighting each data point to decrease the influence of those far from the velocity function. The system also reduces the influence of top and bottom horizons of geological layers by applying data driven techniques that estimate the velocity function in a way that reduces dependence on the boundary conditions. The systems and methods can also create velocity models based on data from a set of wells, applying a well weights method to reduce the influence of outlier wells and thereby prevent wells with aberrant data from degrading a correct velocity model.

Abstract: A method to correct errors in a conversion from time gather to angle gather using slant stacks wherein the slant stacking is performed along a direction that is normal to a dip or along three orthogonal directions. The slant stacking is performed in various domains.

Abstract: Systems, methods, and computer-readable media for modeling a fracture network are provided. The method includes mapping a sub-seismic data set to a portion of a seismic-resolution data set, and defining a fractal region of the seismic-resolution data set containing the portion thereof to which the sub-seismic data is mapped. The method also includes generating a training image for sub-seismic scale characteristics of the one or more fracture networks of the seismic-resolution data set using the portion of the seismic-resolution data, and modeling the sub-seismic scale characteristics of the one or more fracture networks of the fractal region of the seismic-resolution data set outside of the portion, using the training image.

Abstract: An improved methodology for managing hydrocarbon exploration of at least one prospect. The methodology involves iterative processing that allows decision makers to iterate on assumptions and refine underlying probabilistic models as well as optimize the set of recommended exploration activities that are to be performed over time as additional knowledge is gained.

Abstract: Systems and methods include seismic data stacking derived from a set of image volumes. Stacking includes finding a sub-set of seismic image volumes (and in some implementations their respective stacking weights) or multiple realizations of sub-set of seismic image volumes from a given set that are consistent and similar to each other. Some or all of the input seismic image volumes can be stacked together as they would be with a conventional stack. However, the signal-to-noise ratio can be enhanced by only stacking those volumes that contain consistent and relevant information. Optimal stacking can utilize an algorithm that can be implemented in a moving window fashion.

Abstract: A methodology improves sampling and characterization of heterogeneous, unconventional hydrocarbon-bearing regions. The methodology is designed to integrate consistently across measurements and scales. Additionally, the methodology involves characterizing various scales, such as regional-scale heterogeneity, wellbore-scale heterogeneity, core-scale heterogeneity, sample-scale, and pore-scale heterogeneity. The results are integrated across the multiple scales based on results obtained from the characterization of the scales. The methodology further comprises determining data propagation across the multiple scales in a hydrocarbon-bearing region.

Abstract: Numerical simulations of elastic wave propagation algorithms are critical components for seismic imaging and inversion. Finite-difference schemes yield good efficiency but cannot ensure the accuracy of the high frequency component. Pseudo-spectral algorithms are accurate up to the Nyquist frequency, but its efficiency depends on the optimization of the fast Fourier transform (FFT) algorithm. The conventional FFT algorithms are optimized for signal processing, in which problems are generally one dimensional time series. For 3D wave propagation, FFT algorithms have the potential to be further optimized. Under current computer hardware architecture, a vectorization scheme for high dimensional FFTs is presented. Compared to conventional numerical scheme implementations, the systems and methods disclose herein has the best performance on the slowest or higher dimensions of data.

Abstract: Acquired data that corresponds at least in part to a target structure is received. One or more subsets of a first type are formed from the acquired data. The one or more subsets of the first type are converted to one or more subsets of a second, different type.

Abstract: According to a preferred aspect of the instant invention, there is provided herein a system and method for extending zero-offset or stacked wave-equation illumination analysis into the angle-gather domain, where it becomes an appropriate tool for assessing the effects of complex overburden on AVA response. A preferred method for doing this involves first creating an angle gather that has a perfect AVA response (i.e. a constant amplitude as a function of angle). This gather is then preferably used as a reflectivity map that is fed into a demigration process which creates modeled data that by construction carries with it a completely flat reflectivity signature. Remigration of such a data set then results in a gather on which any amplitude variation is more likely to be a measure of illumination effects alone. The resulting AVA signature on the gather can then be used to assess the validity of the AVA response on modeled or actual data, resulting in a useful AVA risk analysis.

Abstract: Method for reconstructing subsurface Q models (110) from seismic data (10) by performing ray-based (60), centroid frequency shift (50) Q tomography. The seismic source waveform's amplitude spectrum is approximated by a frequency-weighted exponential function of frequency (40), having two parameters to adjust to fit the frequency shift data, thereby providing a better fit to various asymmetric source amplitude spectra. Box constraints may be used in the optimization routine, and a multi-index active-set method used in velocity tomography is a preferred technique for implementing the box constraints (100).

Abstract: Method and system is described for reducing sensitivity imbalance issues and/or implements target-oriented tomography to enhance tomographic inversion for velocity model building. The method may include performing a preparation stage to construct a measurement vector from seismic data and a kernel matrix from ray-path information; performing a sensitivity optimization stage to generate a data weighting vector; and performing a property optimization stage to reconstruct a subsurface model of one or more geophysical properties.

Abstract: First-order free-surface multiples recorded in VSP data or reverse VSP data are processed using VSP/CDP method to produce an image of the subsurface. This image produces a larger coverage than that obtained in 3-C 3-D processing of reflection data acquired in the VSP.

Abstract: A method for determining an acoustic anisotropy of a subterranean formation includes measuring acoustic wave slownesses at three or more toolface angles while rotating a logging while drilling tool in a borehole. Compressional, shear, and/or guided wave slownesses may be measured. The measured slownesses are fit to a mathematical model to obtain maximum and minimum slownesses. The maximum and minimum slownesses are processed to determine the acoustic anisotropy of the formation.

Abstract: Systems and methods perform correction of velocity cubes for seismic depth modeling. An example system receives a velocity model defined in the time domain for seismic modeling of a subsurface earth volume and receives well depth data associated with the subsurface earth volume. The system updates an average velocity cube associated with the velocity model to correct depth-converted time horizons to accord with known well markers, thereby increasing the accuracy and correctness of the velocity model.

Abstract: A method for quantitative analysis of time-lapse seismic data of a reservoir, including: obtaining a plurality of compressional and shear velocities from a seismic inversion analysis; selecting a rock physics model based on a property of the reservoir; calculating a transform function using the rock physics model, where the transform function transforms variations in the plurality of compressional and shear velocities into variations in saturation and pore pressure; calculating a transform grid performing a domain transformation of the transform function; obtaining a plurality of cloud points from the seismic inversion analysis and the transform grid; and overlaying the plurality of cloud points onto the transform grid to estimate a plurality of reservoir parameters of the reservoir.

Abstract: Method for converting seismic data to obtain a subsurface model of, for example, bulk modulus or density. The gradient of an objective function is computed (103) using the seismic data (101) and a background subsurface medium model (102). The source and receiver illuminations are computed in the background model (104). The seismic resolution volume is computed using the velocities of the background model (105). The gradient is converted into the difference subsurface model parameters (106) using the source and receiver illumination, seismic resolution volume, and the background subsurface model. These same factors may be used to compensate seismic data migrated by reverse time migration, which can then be related to a subsurface bulk modulus model. For iterative inversion, the difference subsurface model parameters (106) are used as preconditioned gradients (107).

Abstract: 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.

Abstract: A method for estimating subsurface elastic parameters is described herein. One or more slowness vectors may be determined based on a vertical seismic profile of a subsurface area. A model containing anisotropy parameters and a well deviation estimate may be generated based on survey data. The slowness vectors may be corrected for the well deviation estimate based on the model. One or more modeled slowness vectors may be calculated using the corrected slowness vectors and the anisotropy parameters in the model.

Abstract: A method of predicting the pressure sensitivity of seismic velocity within reservoir rocks includes defining the degree of cementation of rock as at least one of friable sand, partially cemented rock and cemented rock. For rock including friable sand, a first model specifying a dependence of seismic velocity upon pressure is defined. For rock including partially cemented rock, a second model specifying a dependence of seismic velocity upon pressure and a weighting function accounting for a degree of cementation of the rock is defined. For rock including cemented rock, a third model demonstrating an insensitivity of seismic velocity to pressure is defined. For a given dry rock moduli and porosity, the method includes determining a degree of cementation, selecting the appropriate model, and using the selected model to predict the sensitivity of seismic velocity to pressure.

Abstract: A method for selecting parameters of a seismic source array comprising a plurality of source elements each having a notional source spectrum is described, the method comprising calculating a ghost response function of the array; calculating directivity effects of the array; and adjusting the parameters of the array such that the directivity effects of the array are compensated by the ghost response to minimize angular variation of a far field response in a predetermined frequency range. A method for determining a phase center of a seismic source array is also related, the method comprising calculating a far field spectrum of the array at predetermined spherical angles, and minimizing the phase difference between the farfield spectra within a predetermined frequency range by adjusting a vertical reference position from which the spherical angles are defined.

Abstract: The invention is a method for geological structure contour modeling and imaging beneficial for quality control and evaluating aerial extent parameter during seismic survey design, quality control of process of migration during processing stage of seismic data, and quality control of structure maps during interpretation of 3-D seismic volume. This method provides a quick and efficient parametric 3-D representation of geologic structures, also allows the use of existing depth data for structure contour modeling and imaging. Normal incident rays, either linear or curved, are traced starting from points along selected contours of structural surface and ending at imaged points on the recording surface to define projected location of the imaged structure contours at the recording surface. Further analysis and quality control is conducted by generating structure maps utilizing third party software using structure contour data, and data for the corresponding contours imaged on the recording surface.

Abstract: The invention discloses a way to recover separated seismograms with reduced interference noise by processing vibroseis data recorded (or computer simulated) with multiple vibrators shaking simultaneously or nearly simultaneously (200). A preliminary estimate of the separated seismograms is used to obtain improved seismograms (201). The preliminary estimate is convolved with the vibrator signature and then used to update the seismogram. Primary criteria for performing the update include fitting the field data and satisfying typical criteria of noise-free seismograms (202). Alternative ways to update are disclosed, including signal extraction, modeled noise extraction, constrained optimization based separation, and penalized least-squares based separation. The method is particularly suited for removing noise caused by separating the combined record into separate records for each vibrator, and is advantageous where the number of sweeps is fewer than the number of vibrators (200).

Abstract: According to the invention, elastic parameters, including density, pressure wave propagation speed, and/or shear in pervious layers located in a dense underground area along an array of horizontal positions, are estimated by inverting 4D seismic data. Firstly, an estimate of variations in the elastic parameters in one or more starting positions of the array, which can be located on bored wells within the area in question, is obtained. Then, a propagation algorithm is used in order to gradually carry out the 4D data inversion on the basis of the starting positions. The inversion takes into account the previously estimated parameter variations. A spatial variation in the depth and/or the thickness of the pervious lavers in question can also be taken into account. Propagation is based on positions that are consecutively selected as providing optimal values for a cost function assessed in order to invert the 4D data.

Abstract: Method for deriving a reservoir property change data volume from time shifts used to time-align 4D seismic survey data (31). The time alignment is performed on at least one angle stack of 4D data to determine a time-shift data volume (32). When multiple angle stacks are used, the time shifts are corrected to zero offset. A running time window is defined, and within each window the time shifts are best fit to a straight-line function of time (depth), one angle stack at a time (33). The slopes from the straight line fits from different angle stacks are averaged at each voxel in the data volume, which yields a reservoir properties (?v/v) data volume (34). This data volume may be filtered with a low-pass filter to improve signal-to-noise (35). The resulting data volume may be merged with the 4D data volume to expand its bandwidth (36), or it may be converted into a reservoir saturation and pressure change data volume (38) using a rock-physics model (37).

Abstract: Method for estimating fluid heterogeneity in a subsurface region from seismic wave attenuation or velocity dispersion that is either measured or extracted from geophysical data (210). A rock physics model in the form of a mathematical relationship is selected that relates attenuation or velocity to frequency and to physical properties that are related to fluid heterogeneity (220). The model, or asymptotes (230) representing the model's behavior at frequency extremes, is inverted (240) and that relationship is used to obtain (250) one or more of the physical properties related to fluid heterogeneity, such as characteristic length scale for fluid saturation heterogeneities (270) and relative volume fractions of the fluids saturating the pore space (280).

Abstract: A method for generating an illumination map. The method includes receiving an earth model that represents one or more properties of the earth. The method then includes receiving a target area in the earth model and propagating one or more wavefields from the target area to a potential seismic data acquisition region in the earth model. After propagating the wavefields, the method includes decomposing the propagated wavefields into one or more subsets of the propagated wavefields and creating the illumination map based on the subsets of the propagated wavefields. The illumination map may indicate one or more contributions of one or more synthetic source and receiver pairs for illuminating the target area in the earth model. The method may then include creating a seismic survey design based on the contributions.

Abstract: A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. These dynamic particle parameters are stored in a form for display. Maximum values of the dynamic particle parameters may be interpreted as reservoir locations. The dynamic particle parameters may be particle displacement values, particle velocity values, particle acceleration values or particle pressure values. The sensors may be three-component sensors. Zero-phase frequency filtering of different ranges of interest may be applied. The data may be resampled to facilitate efficient data processing.

Abstract: A technique includes receiving seismic data, which are indicative of pressure measurements and pressure gradient measurements acquired in a seismic survey of at least one subterranean formation. The technique includes modeling an image of the subterranean formation(s) as a function of the pressure measurements and the pressure gradient measurements. The technique includes determining the image based on the modeling.