Abstract: 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 ??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).

Abstract: A system for monitoring seismicity during fluid injection at or near a hydrocarbon reservoir comprising: a first set of seismic sensors for deployment at a site for collecting seismic data; a second set of seismic sensors for sub-surface deployment at the site at a depth lower than the first set of seismic sensors for collecting seismic data, the first set of seismic sensors having a lower frequency response than that of the second set of seismic sensors; and a data collection system in communication with the first and second set of sensors.

Abstract: A system and method are provided for determining a broadband high definition reflectivity based image for a geographical area of interest (GAI). The system and method generate a conventional reflectivity image based on acquired seismic data for the GAI, generate a high frequency (HF) velocity model of the GAI based on the acquired seismic data, convert the HF velocity model into a low frequency (LF) reflectivity image, and adaptively merge the LF reflectivity image with the conventional reflectivity image to form the broadband HD reflectivity image of the GAI.

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 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: A method for processing seismic data including contiguous-sweep records corresponding to rotated sweep segments includes attenuating harmonics and generating stacked traces, each stacked trace being a weighted sum of traces corresponding to same location in the subsurface, based on seismic data from different seismic receivers, following plural shots at plural locations.

Abstract: A method of processing seismic data is provided in the seismic data is acquired at a plurality of locations and the method comprises interpolating and/or extrapolating the seismic data, thereby to estimate seismic data at a target location different from the plurality of locations. The interpolating and/or extrapolating the seismic data is performed in a polar co-ordinate system. The method may provide for, among other things, accuracy of estimation; particularly at short offsets from the seismic source. The polar co-ordinate system used may be chosen to approximate the seismic wavefront in an earth model, for example in an earth model in which properties vary only with depth.

Abstract: Methods for attenuating multiple reflections in seismic data by predicting the multiples using wavefield extrapolation modeling, which uses one-way wavefield propagation in both the up and down directions to predict internal multiples up to a specified order.

Abstract: This is a method of separating simultaneous sources that uses an inversion-type approach. Each source will preferably activated at a random time with respect to the others. These random delays tend to make the interference between sources incoherent while the reflections create coherent events within a series of shots. The shot separation is performed via a numerical inversion process that utilizes the sweeps for each shot, the start times of each shot, and the coherence of reflection events between nearby shots. Implementation of this method will allow seismic surveys to be acquired faster and cheaper.

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: Seismic acquisition systems are disclosed that allow contemporaneous seismic sources to be separated from a composite signal comprising two or more constituent seismic sources. In some embodiments, a representation of the composite signal may be developed that includes a noise contribution of undesired signals present in the composite signal. Additionally, an operator, referred to herein as an “annihilator”, may be developed such that it may be conditioned and inverted to minimize undesired noise contributions in the composite signal. This inversion may assist in recovering the constituent seismic sources from the composite signal. Furthermore, in some embodiments, the accuracy with which the constituent source measurements are approximated may be increased by implementing them as random sweeps having a conventional length.

Abstract: A method for processing seismic data acquired using the same seismic survey setup over long periods of time includes acquiring sets of seismic data using the same seismic survey setup over multiple days, the sets being gathered as repeated seismic data. The method further includes estimating a time-variable wavelet corresponding to unwanted waves, and determining a propagation of the time-variable wavelet, which propagation is assumed to be constant in time, by solving an inverse problem using the repeated seismic data and the estimated time-variable wavelet. The method also includes extracting signal data by subtracting a convolution of the estimated time-variable wavelet and the propagation from the repeated seismic data.

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: Method for velocity model building and analysis using wavefield-coordinates reflection operators in wave-equation migration or reverse-time migration.

Abstract: Microseismic mapping using buried arrays with the integration of passive and active seismic surveys provides enhanced microseismic mapping results. The system is initially set up by recording seismic data with the buried array installation while shooting a significant portion of the 3D surface seismic survey. The 3D surface seismic survey provides the following data: shallow 3D VSP data from the buried arrays; P-wave and converted wave data for the area covered by the buried array that benefits from the planned data integration processing effort; and microseismic data and associated analysis.

Abstract: An embodiment of the invention includes simultaneous drive signals whose respective phase angle offset(s) varies over a portion or duration of the simultaneous sweeps. Other embodiments are discussed herein.

Abstract: A technique includes receiving seismic data acquired in a survey of a region, the region being associated with locations; processing the seismic data to estimate at least one frequency dependent surface wave property over the region; based at least in part on the estimated frequency dependent surface wave property(ies), determining a frequency dependent data processing geometry for each location; and processing the seismic data based at least in part on the determined data processing geometries to derive a spatially continuous representation of a surface wave property across the region.

Abstract: A system for modeling the output signal emanating from a seismic vibrator based on a superposed collection of damped harmonic oscillators, whose critical parameters are determined from signals from accelerometers on the baseplate and reaction mass portions of the vibrator together with the input force (pilot sweep). This modeled output signal is a more accurate representation of the seismic signal that propagates into the earth and may be used in the cross-correlation process to significantly enhance the accuracy of the recorded seismic data. Additionally, by modeling the output signal on a shot by shot basis, any changes in the ground's surface can be monitored and/or documented, and, if required, the sweep parameters can be varied shot by shot for optimum performance.

Abstract: Determining geological layer location in a subterranean formation, including receiving seismic data representing an interaction of the geological layer with propagation of a seismic wave, identifying a source wavelet representing a portion of the seismic wave impinging on a boundary of the geological layer, providing a geological layer template of the geological layer including primary and secondary reflection interfaces associated with reflectivity based on material properties of the geological layer, generating a wavelet response template by applying the source wavelet to the geological layer template using a mathematical convolution operation to model seismic wave interference caused by the primary and secondary reflection interfaces, identifying an extremum of the seismic data, and determining, based on the extremum, the location of the geological layer in the subterranean formation using the wavelet response template.

Abstract: A device, medium and method for de-blending seismic data associated with a subsurface of the earth. The method includes a step of receiving seismic data “d” recorded with one or more land receivers, wherein the seismic data includes shot recordings generated by plural sources that are simultaneously actuated; a step of forming either a continuous receiver trace or trace segments from the received seismic data; a step of selecting plural overlapping spatial blocks that cover the surface shot locations; a step of assigning the shot recordings to the plural overlapping spatial blocks; a step of applying a mathematical technique to the recordings to determine de-blended data; and a step of generating an image of the subsurface based on the de-blended data.

Abstract: Methods and systems for a surface-consistent amplitude and deconvolution simultaneous joined inversion are described. A one-pass estimation using input trace data for generating gain and deconvolution operator based on a least squares iteration method. A series of iterations are performed simultaneously and independently estimating amplitude scalars and autocorrelation spectra with a common convergence criterion. The gain and deconvolution operator can further be used to correct the input trace data for pre-stack or stack imaging.

Abstract: Embodiments use seismic processing methods that account for the spatial variability of surface wave velocities. Embodiments analyze surface wave properties by rapidly characterizing spatial variability of the surface waves in the seismic survey data (302). Filtering criteria are formed using the spatial variability of the surface waves (204). The filtering criteria can then be used to remove at least a portion of the surface waves from the seismic data (206, 319). The rapid characterization involves estimating a local group velocity of the surface waves by cross-correlation of the analytic signals (302).

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: Seismic systems and methods are provided to collect variable seismic data, for coordinating source energy and receiver data as well as using both to obtain high resolution seismic data.

Abstract: Generating an image of an interior of the Earth from a seismic survey using multiple sources. The multiple sources may be fired simultaneously and the data received by seismic sensors in the seismic survey may be decomposed so that seismic data generated by each of the multiple sources may be determined. Decomposing of the received data may be performed using frequency diverse basis functions and converting the data separation problem into an optimization problem, which can be a one-norm or zero-norm optimization problem in frequency-space domain. The decomposed data may be used to generate the image of the Earth's interior.

Abstract: A method including analyzing seismic data relating to a producing hydrocarbon reservoir is disclosed. The seismic data includes first and second sets of seismic data obtained at different times. An interval composed substantially of hard rock is identified in the hydrocarbon reservoir. 4D seismic attributes for the region are calculated. Rock physics relationships are applied to seismic data related to the interval according to the permeability associated therewith. A fluid saturation change or a pressure change of the interval is inferred based on outputs of the first or second sets of rock physics relationships and the calculated 4D attributes for the interval. The inferred fluid saturation change or pressure change of the interval is outputted.

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: Embodiments are directed to systems and methods (200, 300) that enable spatial variability of surface waves to be accounted for in dispersion correction in seismic data processing. This yields superior surface wave noise mitigation, with reduced likelihood of attenuating signal. Embodiments are operative with spatially inhomogeneous media.

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.

Abstract: 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.

Abstract: A method for processing geophysical data. The method includes applying a first interferometry on an estimate of a direct ground roll between a receiver location and one or more boundary source locations and an estimate of a direct ground roll between one or more boundary receiver locations and each boundary source location to generate an interferometric estimate of a direct ground roll between the receiver location and each boundary receiver location. The method then includes applying a second interferometry on geophysical data between the source location and each boundary receiver location and the interferometric estimate of the direct ground roll between the receiver location and each boundary receiver location to generate an interferometric estimate of a direct and scattered ground roll between the source location and the receiver location.

Abstract: The invention is a method for extrapolating missing near-offset seismic data (101) so that the data may be used, for example, in SRME or another multiple-reflection elimination method. The invention uses the reciprocity principle (102) to relate two seismic states (acoustic or elastic) that can occur in a time-invariant, bounded domain in space. One of these states represents the physical experiment for the acquisition of the actual seismic data where near-offset traces are missing, and the other state represents a synthetic experiment with no missing near offset traces, computer-generated on a much simpler earth model. The reciprocity relationship used to relate these two states is iteratively inverted for the missing near-offset traces (103), preferably using only part of the synthetic data (102) so as to reduce inversion artifacts. The reference model acts as a constraint on the near-offset extrapolation.

Abstract: Disclosed herein are various embodiments of methods and systems for determining the orientation and direction of first motion of a fault or fracture by optimizing an azimuthally-dependent attribute of signals generated by microseismic sources, comprising: recording microseismic data traces using a of sensors located at a plurality of sensor positions; subdividing the subsurface volume into spatial volumes corresponding to selected time intervals and comprising a plurality of voxels; for each voxel, applying a time shift to the microseismic data traces that is substantially equal to a travel time from each voxel to the corresponding sensor position, and determining for the voxel the orientation and direction of first motion of the fault or fracture corresponding to a maximum value for the voxel of at least one azimuthally-dependent attribute of the microseismic data traces.

Abstract: A method and device for monitoring a subsoil zone, wherein a plurality of receivers are arranged on a surface of the soil or near said surface, straight above a geological zone to be monitored, comprising the following steps: generating a set of reference seismic data; recording seismic data by means of said receivers; correlating the seismic data recorded with the reference seismic data; comparing each trace of the correlated data, with correlated traces located in a vicinity of said trace, in order to evaluate a similarity of each correlated trace with the adjacent correlated traces; and, detecting a microseismic event occurring in the subsoil zone by analysing said similarity. The method and device enables real-time monitoring.

Abstract: The invention relates to a method for monitoring a subsoil zone, wherein a plurality of receivers are arranged on a surface of the soil or near said surface, straight above a geological zone to be monitored, comprising the following steps: generating a set of reference seismic data recording seismic data by means of said receivers; correlating the seismic data recorded (52) with the reference seismic data; comparing each trace of the correlated data, with correlated traces located in a vicinity of said trace, in order to evaluate a similarity of each correlated trace with the adjacent correlated traces, detecting a microseismic event occurring in the subsoil zone by analysing said similarity. This method enables real-time monitoring.

Abstract: Systems and methods for seismological sounding with acoustic signals and, more particularly, systems and methods for performing geophysical surveys using spread spectrum acoustic waves generated by non-impulsive sources. A spread spectrum signal is generated and coupled to a medium that is to be sounded for propagation of an acoustic wave through the medium. One or more return signals are received from the medium that are generated by interaction between the acoustic wave and the medium. The return signals are possessed to obtain seismic sounding data describing the structural features of the medium.

Abstract: Provided are an apparatus and method for imaging the subsurface structure of a target area by using waveform inversion. In the apparatus and method, the subsurface structure of a target area is estimated using waveform inversion of a seismic signal in the frequency domain, the Laplace domain, or the Laplace-Fourier domain, and an objective function is defined by applying a weighting function such that the objective function makes a different contribution for each frequency, each Laplace damping constant, or each Laplace-Fourier damping constant. The objective function is not limited to a particular type of objective function and a weighting function can be automatically determined when a gradient vector for each frequency, each Laplace damping constant, or each Laplace-Fourier damping constant is normalized.

Abstract: A walkaway VSP survey is carried out using a receiver array. Using a vertical VSP survey and arrival times of surface multiples on the walkaway VSP, vertical interval velocities and the anisotropy parameters ? and ? are estimated. This may then be used to process surface seismic data to do a prestack depth migration of surface seismic data and used for interpretation. For multi-azimuthal walkaway or 3D VSP data, we determine two VTI parameters ? and ? for multi-azimuth vertical planes. Then we determine five anisotropic interval parameters that describe P-wave kinematics for orthorhombic layers. These orthorhombic parameters may then be used to process surface seismic data to give a stacked image in true depth and for the interpretation purposes.

Abstract: A method of passive surveying comprises generating one or more detected signals by passively detecting a signal generated within a subsurface earth formation due to a seismoelectric response or an electroseismic response in at least one porous subsurface earth formation containing at least one fluid, and processing the one or more detected signals to determine at least one property of the subsurface earth formation.

Abstract: A technique includes obtaining seismic data acquired by seismic sensors of a composite seismic signal that is produced by the firings of multiple seismic sources. The technique includes modeling the seismic data as being a function of models for the sources and linear operators and defining desired constraints on the models. The technique includes simultaneously determining the models based on the modeling and the desired constraints. The datasets are generated based on the determined models. Each dataset is indicative of a component of the composite seismic signal and is attributable to a different one of the seismic sources.

Abstract: An apparatus for allocating a current measurement value for a geographical position to a map object of a geographical map, wherein the current measurement value originates from a series of adjacent measurement values for adjacent geographical positions, having a processor for determining a first probability measure indicating whether the current measurement value can be allocated to a first map object to which at least one adjacent measurement value of the series has already been allocated previously, and for determining a second probability measure indicating whether the current measurement value can be allocated to a second map object having an intersection with the first map object, if the first probability measure indicates that an allocation of the current measurement value to the first map object is unlikely.

Abstract: A method for evaluating subsurface formations includes deploying at least two intersecting seismic transducer lines above an area of the subsurface to be surveyed. Each line includes spaced apart seismic transmitters on one side of the intersection and spaced apart seismic receivers on the other side. On each line, one of the transmitters is actuated and signals are detected at one of the receivers. The foregoing is repeated for each of the remaining receivers. The foregoing is then repeated for each of the remaining transmitters on each line. The detected signals are processed to enhance both specular and non-specular seismic events in the subsurface. The enhanced events may be stored and/or displayed.

Abstract: A method of analysing the dynamic behavior of fracture networks in a seismic volume is provided. The method includes providing a plurality of seismic time lapse vintages of the same geological volume; identifying and parameterising fractures within fracture networks of each vintage; determining one or more distributions of fracture parameters for the fracture networks of each vintage; and identifying changes to the fracture networks by comparing corresponding distributions across the vintages.

Abstract: There is provided herein a method of passive seismic acquisition that utilizes real time or near real time computation to reduce the volume of data that must be moved from the field to the processing center. Much of the computation that is traditionally applied to passive source data can be done in a streaming fashion. The raw data that passes through a field system can be processed in manageable pieces, after which the original data can be discarded and the intermediate results accumulated and periodically saved. These saved intermediate results are at least two, more likely three, orders of magnitude smaller than the raw data they are derived from. Such a volume of data is trivial to store, transport or transmit, allowing passive seismic acquisition to be practically used for continuous near-real-time seismic surveillance.

Abstract: A method for quantitatively evaluating and using multiple geophysical datasets and external constraints for performing velocity model building through simultaneous Joint Inversion and finalized at the improvement of seismic depth images in particularly difficult geology and hydrocarbon high-risk exploration areas is disclosed, which involved the development of techniques: to derive an iterative depth-domain seismic imaging workflow which allows for the simultaneous use of seismic post-migration Common Image Gather residuals together with first arrival (First Break) residuals in conjunction with gravity data and magnetotelluric data; to include in the iterative Joint Inversion workflow the setup of external a-priori constraints as well as of external constraints weighted by probability functions; to include in the iterative Joint Inversion workflow the probabilistic evaluation of the relationships among geophysical parameters that are distinguished into analytical, empirical and structural (i.e.

Abstract: A new seismic attribute is disclosed along with its use to locate and classify seismic waveform anomalies and use them to construct objects and from them geologic surfaces (77) and bodies (75) from which hydrocarbon potential (or quality control of the seismic acquisition and processing (71)) may be assessed (79). The seismic attribute is constructed (74) from determinations of phase residues in the seismic data volume (72), preferably using complex trace analysis but alternatively by comparing neighboring waveforms for disappearing waveshape inflections. It is shown that in a data volume of the new attribute, non-zero values form strings and loops that may be associated with objects (geobodies) or surfaces such as unconformities or flooding surfaces. Methods of classification and selection (76) to reduce the number of objects generated are provided.

Abstract: A method of locating subsurface hydrocarbon reservoirs includes acquiring seismic data, extracting seismic data attributes from the seismic data, calculating exemplar data group probability density function values using distribution values associated with the seismic attributes and applying Bayesian inversion to determine the likelihood of subsurface hydrocarbons.

Abstract: Methods and apparatuses are disclosed for replacing the individual receivers used with a seismic interferometry process with an array of seismic receivers and then manipulating the array data in order to measure and modify the typical non-uniform directionality function of the background seismic energy. The non-uniform directionality function is a significant cause of noise with seismic interferometry. Furthermore, the array of receivers may be used to significantly enhance the preferred reflection energy and damp undesirable near surface energy. The directionality function may be modified by using an array of receivers for the virtual source location of seismic interferometry to measure the non-uniform directionality function, generating multiplication factors, and applying the multiplication factors to convert the measured directionality function into a desired directionality function.

Abstract: A system for communication through subterranean structures underneath a surface comprises at least one exploration tool adapted to penetrate into the underground, at least one transmitter, at least one receiver, and signal transfer means for transmitting signals between the exploration tool and a recording unit arranged overground, where at least one of the transmitter or receiver is integrated in the exploration tool. The exploration tool is a device which is able to penetrate into the underground in order to bring equipment into the underground independent of any existing or new wells.