Abstract: Computing device, computer instructions and method for denoising seismic data recorded with seismic receivers. The method includes receiving the seismic data recorded with the seismic receivers, wherein the seismic data is recorded in a time-space domain; applying with a computing device a high resolution transform to the seismic data in the time-space domain to obtain transformed seismic data in a different domain than the time-space domain, such that the method is amplitude preserving; determining regions of noise and regions of true signal in the transformed seismic data; scaling down the regions of noise; and reverse transforming the transformed seismic data to the time-space domain.

Abstract: A method of processing stratigraphic data comprising a plurality of stratigraphic features, such as horizon surfaces, within a geological volume is provided. The method includes the steps of: extending a plurality of spaced sampling traces through the volume to traverse the stratigraphic features; and assigning the stratigraphic features respective relative geological ages. On each sampling trace, the relative geological age of each stratigraphic feature traversed by the sampling trace in the direction from geologically younger to geologically older stratigraphic features is increased in relation to the relative geological age of its preceding stratigraphic feature, under the condition that each stratigraphic feature takes the same relative geological age across all the sampling traces by which it is traversed.

Abstract: A method for fault and fracture identification based on seismic data representing a geological section using dispersion properties of reflected and diffracted waves. The method includes scanning N parameters associated with the seismic data. The array includes the coordinate axes of the angle of emergence (?), the radius of curvature of the wave front (R) and either time or depth samples. The method also includes processing the N parameters, generating a new image having a cross-sectional shape associated with one of the reflected and diffracted waves, calculating parameters DS and LS, evaluating DS for the case of fracture characterization, and comparing, for the case of fault identification, parameter LS with a threshold value defining the type of wave as one of the reflected and diffracted wave, the cross-sectional shape being substantially circular for the reflected wave, and being elliptical for the diffracted wave.

Abstract: A computer-implemented method for processing data includes accepting a first collection of traces corresponding to signals received over time due to reflection of seismic waves from subsurface structures. A Radon transform is defined with respect to a set of wavefront parameters of the seismic waves. The transform defines a summation of amplitudes of the seismic waves over trajectories defined by the wavefront parameters. The Radon transform is applied to the first collection of traces, so as to convert the first collection into a multidimensional data array that is defined as a function of at least two of the wavefront parameters. The multidimensional data array is processed to produce a second collection of traces having an improved imaging quality with respect to the first collection. The second collection of traces is processed to generate a seismic image of the subsurface structures at the improved imaging quality.

Abstract: A method for stratigraphic analysis of seismic data, known as GeoLeaf, comprises: selecting a seismic data volume comprising a plurality of samples; selecting a number of horizons (TH, BH1 TPH, BPH, SMH) within the seismic data volume; selecting a scale of interest within the seismic data volume, which ranges from 500 m up to the size of the entire seismic data volume; applying an attribute function to at least one of the selected number of horizons (TH, BH, TPH, BPH, SMH) at the selected scale of interest; and displaying a stratigraphic attribute, which represents a geologic feature, such as a seismic fades attribute (FM), an unconformity attribute (Zmax/Z) and/or a thinning attribute (Z1/Z2).

Abstract: A visualization method for the computation and display of seismic attributes from time-frequency spectral analysis enables high resolution investigation of 3D seismic data for the exploration of oil and gas. First, high frequency resolution time derivative or space derivative of the amplitude and phase spectra of time-windowed signals are computed. Second, the derivatives are transformed into seismic attributes that are suitable for seismic data processing or interpretation. Applications for the method are illustrated with graphical screen 3D volume displays of dip and azimuth, curvature and faults. Aside from providing high resolution these displays may improve the productivity of a seismic interpreter or data processor.

Abstract: A method and visualization apparatus for spectral analysis of time-and-space varying signals enables high resolution investigation of 3D seismic data for the exploration of oil and gas. The method extrapolates multi-resolution short windows into an average long window then computes its FFT. Extrapolation uses the continuity relationship between data inside and outside of short windows. Applications of the method are illustrated with graphical screen 3D volume displays of amplitude spectra, dip and azimuth, curvature and faults (figure below). Aside from high resolution these displays improve the productivity of a seismic interpreter.

Abstract: A method and system for processing synchronous array seismic data includes acquiring synchronous seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data propagation process is applied to the synchronized array measurements to obtain dynamic particle parameters associated with subsurface locations. A maximum energy density imaging condition is applied to the dynamic particle parameters to obtain imaging values associated with subsurface locations. Subsurface positions of energy sources are located from the relative maximum of a plurality of the imaging values associated with subsurface locations.

Abstract: An apparatus and method for mapping a water pathway. A group of sensors can be employed for detecting one or more features associated with the water pathway in a direction of flow through the water pathway. A buoyant vessel maintains the sensors, and the sensors assist in compiling data indicative of the detected features. The velocity in the direction of flow through the water pathway can be then determined based on data indicative of the detected feature(s). A mapping of the water pathway can be thereafter generated utilizing the velocity with respect to the features detected by the sensors.

Abstract: Embodiments of the invention provide a system and method for partitioning data for modelling a geological structure including laterally partitioning the data into multiple columns, where each column may be substantially laterally centered about a dual fiber and vertically partitioning each column at each of multiple intersection points of multiple surfaces and the dual fiber about which the column may be substantially laterally centered.

Abstract: A system and method for generating images of a subsurface region of interest is provided. In one embodiment, a computer-implemented method of generating images related to a subsurface region of interest includes: accessing, via a central processing unit (CPU), seismic data and an earth model related to the subsurface region of interest; forward propagating a source wavefield using the earth model at a first time interval via at least one external co-processor coupled to the CPU; transferring, at a second time interval, the forward propagated source wavefield to the CPU for compression and external storage; backward propagating the seismic data at the first time interval via the external co-processor to derive backward propagated receiver wavefield; and transferring, at the second time interval, the backward propagated receiver wavefield to the CPU.

Abstract: A step frequency inverse synthetic aperture radar (ISAR) includes a transmitter configured to transmit a transmission pulse at a transmission frequency to a near earth object (NEO), the transmission frequency having a frequency range comprising a starting frequency, an ending frequency, and a step size; a receiver configured to receive a pulse response from the NEO, the pulse response corresponding to the transmission pulse; and a computer configured to determine a 3-dimensional image of the interior of the NEO from the pulse response.

Abstract: Method, system, and computer program product for tracing seismic sections to convert to digital format are provided. The method includes: receiving a scan of a seismic section having multiple overlapping traces measured at spot points; splitting the traces into segments; associating the segments with appropriate baselines; estimating the traces between segments using logical rules; and deriving amplitudes of the traces.

Abstract: Method for obtaining rock parameters such as porosity and vshale directly from inversion of seismic data corresponding to a single trace location. This method is distinguished from existing methods that obtain elastic properties from inversion of seismic data, then relate the elastic parameters to rock lithology parameters such as porosity or vshale because it is accomplished in one step, can incorporate anisotropy and does not require multiple trace locations for stability. The data are separated into partial stacks, and a wavelet is specified for each stack. A set of linearized equations are constructed relating seismic reflectivity to changes in elastic parameters, and another set of linearized equations is constructed relating the changes in elastic parameters to the lithologic parameters. The linearized reflectivity equations are combined with the linearized rock physics equations, convolved with the specified wavelets, and equated to the seismic data.

Abstract: A geophysical model of a subsurface region is generated based on seismic data, e.g., seismic reflection data. Migration and seismic inversion are applied to the seismic data to generate estimates of one or more physical or seismic properties of the subsurface region. Seismic inversion, such as spectral shaping inversion, is applied before or after migrating the seismic data through a variety of techniques that each avoid the amplification of dipping energy while optimizing computational efficiency and/or accuracy.

Abstract: Embodiments of the invention provide a system and method for converting coordinate systems for representing image data such as for example seismic data, including accepting a first set of seismic data, mapping the first set of seismic data to a second set of seismic data, where the dimensionality of the second set of seismic data is less than the dimensionality of the first set of seismic data, and generating image data by processing the second set of seismic data.

Abstract: The invention relates to acquiring seismic data in either land or marine environments, but typically marine environments where a pulse-type source is fired in a distinctive composite pulse like a distinctive rumble. In a preferred embodiment, a number of pulse-type seismic sources, sometimes called an array, are fired in a distinctive composite pulse to be able to identify within the returning wavefield the energy resulting from the composite pulse. Firing the pulse-type sources creates an identifiable signature so that two or more marine seismic acquisition systems with source arrays can be acquiring seismic data concurrently and the peak energy delivered into the water will be less, which will reduce the irritation of seismic data acquisition to marine life.

Abstract: A method for performing chrono-stratigraphic interpretation of a subterranean formation. The method includes obtaining a seismic volume containing stratigraphic features of the subterranean formation deformed by structural events, performing structural restoration of the seismic volume to generate a restored seismic volume by removing deformation due to the structural events, performing a chrono-stratigraphic interpretation based on the restored seismic volume to generate chrono-stratigraphic objects each associated with a respective relative geologic age, and displaying the chrono-stratigraphic objects in a chrono-stratigraphic space according to the respective relative geologic age of each of the stratigraphic objects.

Abstract: A method for performing seismic interpretation of a subterranean formation by enabling dual-domain interpretation of seismic features in the present day depth domain and simultaneously in a structurally restored “mapped” seismic domain. Specifically, seismic interpretation is performed on structurally restored seismic volumes while concurrently viewing the interpretation results in the structural domain. This increases the interpretation confidence by improved correlation of structural deformed events to their pre-structurally deformed geometry. The method includes the ability to progressively remove structural deformation from the seismic volume, corresponding to moving back in geologic time. The interpretation can be performed in either domain (present-day structure or structurally restored to a defined geologic event), and the interpretation will be mapped to any other computed geologic age or present structural age.

Abstract: A method and system of detecting and mapping a subsurface hydrocarbon reservoir includes determining ratio data for a plurality of orthogonal spectral components of naturally occurring low frequency background seismic data. The ratio data may be compared, plotted, contoured and displayed as a subsurface hydrocarbon reservoir map or a hydrocarbon potential map. The ratio data may represent a vertical spectral component of the seismic data over a horizontal spectral component of the seismic data. The subsurface hydrocarbon reservoir map may include contouring the ratio data over a geographical area associated with the seismic data.

Abstract: According to a preferred aspect of the instant invention, there is provided herein a system and method for Interpolation of seismic data with a POCS (projection onto convex sets) algorithm that can produce high quality interpolation results, at a reduced computational cost. In particular, optimizing the threshold calculations, allowing for aliased data, allowing the algorithm to skip unneeded Fourier transforms, and parallelization makes the method more practical and robust. Robust interpolation of aliased data may be done by limiting the calculations of the beginning iterations to the lowest temporal and spatial frequencies included in the data, then gradually allowing higher temporal and spatial frequencies into the following iterations.

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 propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects.

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 propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects.

Abstract: A method and system of detecting and mapping a subsurface hydrocarbon reservoir includes determining ratio data for a plurality of orthogonal spectral components of naturally occurring low frequency background seismic data. The ratio data may be compared, plotted, contoured and displayed as a subsurface hydrocarbon reservoir map or a hydrocarbon potential map. The ratio data may represent a vertical spectral component of the seismic data over a horizontal spectral component of the seismic data. The subsurface hydrocarbon reservoir map may include contouring the ratio data over a geographical area associated with the seismic data.

Abstract: Systems, program product, and methods of suppressing residual water bottom energy in seismic data, are provided. An example of a system, program product, and method can be applied to post-stack datasets and can combine multi-channel deconvolution with novel sorting keys to efficiently identify and suppress residual water bottom energy in common depth point (CDP) stacked seismic data, thereby increasing the resolving power of seismic data leading to an improved interpretation of seismic signals reflected from oil reservoirs.

Abstract: A system, which may be and/or may include a computer system, and method for identifying a fault patch position from a seismic data volume. The system and method may include defining an initial active surface in the seismic data volume; identifying one or more active surfaces by minimizing the value of a function for energy; tracking back the active surfaces to find a set of control points; and producing the fault patch position formed by the set of control points.

Abstract: Seismic data are assembled and stored for a set of cross-correlation lag times to form an array of common image gathers over depth levels of interest. The two dimensional gathers assembled over different lag times form a three-dimensional cube of common image data. The data are analyzed to determine the travel time shift required to equalize upgoing and downgoing wavefields. Events in the common image gathers are then modeled using Green's functions to generate a data set representing the data resulting from processing had a precise velocity model been obtainable from the seismic data. The generated data are then processed with inversion techniques to form a velocity model for seismic data analysis.

Abstract: A method for processing seismic data. The method includes plotting a travel-time curve and one or more actual times that each seismic receiver receives one or more seismograms on a graph. The travel-time curve represents an approximate time that each seismic receiver in a seismic survey area receives the seismograms. The method may further include determining a residual static shift for each seismogram and using the residual static shift to estimate a time shift correction. The residual static shift represents a difference between an actual time in which a seismic receiver received a seismogram and a time on the travel-time curve that corresponds to the actual time. The time shift correction corrects a timing error in the time indicated by the travel-time curve.

Abstract: A long-range lightning detection and characterization system and method. Electromagnetic radiation produced by a lightning strike is sensed at a sensing location and a measured signal representative of the strike is produced that defines an amplitude versus time. A set of reference data containing waveforms comparable to the measured signal is established. The set of reference data defines a set of reference amplitudes versus time, representative of one or more predetermined reference lightning strikes at various predetermined distances, where for each of the distances, the reference lightning strikes have associated therewith various predetermined day/night percentages. The measured signal is compared with the reference data, the comparison including finding a correlation between the measured signal and a correlating waveform in the reference data.

Abstract: Application of nonlinear resonance interferometry is introduced as a new geophysical approach to improve predictability in characterization of subsurface microseismic event analysis and propagation of fracture. In contrast to reflection methods that remove random information noise, nonlinear resonance interferometry exploits the full microseismic acquisition spectrum. In some examples, systems and techniques implement novel computational interactions between acquired microseismic wavefield attributes and a nonlinear system in software to amplify distortions in microseismic noise and exploits injection of synthetic noise, in software format, to fracture events.

Abstract: To perform a marine survey, a streamer is deployed into a body of water, where the streamer has plural first sensors to perform a subterranean survey. Indications are received from second sensors in corresponding sections of the streamer, where the indications are regarding which sections are in the body of water. Information is updated regarding which sections of the streamer are in the body of water in response to the received indications.

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 propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects.

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 propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects.

Abstract: To determine fault transmissivity in a subterranean reservoir, fault structures in the subterranean reservoir are identified, and elastic impedance data is computed from well log data and seismic data. Normalization parameters that have a predetermined orientation with respect to the identified fault structures are computed, and elastic impedance flux values are normalized with respect to the normalization parameters, where the normalized elastic impedance flux values are indicative of transmissivities of fault structures in the subterranean structure.

Abstract: To perform a marine survey, a streamer is deployed into a body of water, where the streamer has plural first sensors to perform a subterranean survey. Indications are received from second sensors in corresponding sections of the streamer, where the indications are regarding which sections are in the body of water. Information is updated regarding which sections of the streamer are in the body of water in response to the received indications.

Abstract: Method, apparatus, computer program and data carrier for modeling a multidimensional, heterogeneous structure using a digital processing unit, by means of a grid built up of stacks of multidimensional cells. A cell is bounded by boundary surfaces and represents at least one property of the structure. The composition of a stack, the position of the stacks in the grid and the properties represented by cells are stored in memory means by the processing unit. For modeling a discontinuity, a respective stack is divided into two or more substacks separated by separating surfaces. The composition and the position of the substacks in a respective stack are stored in the memory means. The modeling method enables an accurate and fast computation of properties of the modeled structure or space.

Abstract: A system and method monitor a hydrocarbon reservoir for drainage in volumetric three dimensions. Monitoring between wells is imperative for optimum reservoir management and is achieved by mapping the hydrocarbon fluid pathways in a producing reservoir. Unlike conventional 4D or time-lapse reflection seismic imaging systems that use a controlled active seismic source and records reflected seismic energy at receivers, the system and method exploit the minute vibrations, or micro-earthquakes generated in the reservoir layers that are induced by fluid movement. These microseisms are detected as the fluids move in the reservoir.

Abstract: Described herein is a method for optimizing a plurality of calibration maps for an algorithm of estimation of a control quantity of an internal combustion engine, each of the maps comprising a plurality of calibration values of said control quantity estimated by said algorithm. The optimization method comprises measuring the control quantity, estimating the control quantity, and individually optimizing each calibration map based on the measured control quantity and the estimated control quantity.

Abstract: Fast anisotropy axis values are determined for each bin in seismic data binned by azimuth. A fast azimuth gather is determined within each bin in the seismic data from the fast anisotropy axis values. The earth's subsurface is imaged, using the fast azimuth gathers.

Abstract: To enable analysis of a signal associated with surveying a subterranean structure, a processing system receives a time series of the signal associated with surveying the subterranean structure. A visualization of the time series is generated, where the visualization is a time-based representation of a characteristic of the signal. The visualization enables a determination of whether undesirable variations occur with the signal over time.

Abstract: Application of nonlinear resonance interferometry is introduced as a new geophysical approach to improve predictability in characterization of subsurface porosity, rock and fluid properties. In contrast to reflection methods that remove random information noise, nonlinear resonance interferometry exploits the full seismic acquisition spectrum to assess how low frequency and high-frequency noise is differentially and directly modulated by varying levels of porosity and hydrocarbon content in the lithologies of interest. In some examples, systems and techniques implement novel computational interactions between acquired seismic wavefield attributes and a nonlinear system in software to amplify distortions in seismic noise and exploits injection of synthetic noise, in software format, to detect hydrocarbon traps and lithology changes at spatial scales below seismic resolution, thereby increasing the information value of low-resolution data.

Abstract: Techniques and a system for performing geological interpretation operations in support of energy resources exploration and production perform well log correlation operations for generating a set of graphical data describing the predetermined geological region. The process and system interpret the geological environment of the predetermined geological region from measured surface and fault data associated with the predetermined geological region. Allowing the user to query and filter graphical data representing the predetermined geological region, the method and system present manipulable three-dimensional geological interpretations of two-dimensional geological data relating to the predetermined geological region and provide displays of base map features associated with the predetermined geological region.

Abstract: Method and computer program for accepting controlled-source electromagnetic (“CSEM”) source and receiver data (40) as time series, transforming these data into the time-frequency domain, and reducing these data and survey metadata to a form suitable for interpretation or inversion. The invention includes: a number of processing tools or programs (30), each designed to take a specific action on CSEM data or metadata, combine data types in some way, and/or provide a visual representation of data; a Graphical User Interface (32) to specify the action of specific tools (34) on specific data, supply parameters to tools, and monitor progress of the processing project; and a specified common internal data format, so that processing tools may be applied in various orders (36) during different processing flows and processed CSEM data can be passed on to interpretation or inversion systems.

Abstract: The present application relates to a system and method for real-time monitoring and failure prediction of electrical submersible pumps. The design includes generating a failure prediction value with a management system by calculating a percentage change of the respective first measurement values and the corresponding user-supplied stable operating values, the failure prediction value representing likelihood of failure of the electrical submersible pump.

Abstract: A method for seismic event mapping includes selecting a plurality of subvolumes representing possible locations of origin of a seismic event in the Earth's subsurface. For each subvolume a plurality of possible directions of motion of subsurface formations is selected. For each subvolume and each possible direction of motion, polarity correction is applied to seismic signals recorded at a plurality of positions proximate a volume of the Earth's subsurface to be evaluated. The polarity correction is based on the direction of motion and the position of each seismic sensor with respect to the subvolume. The recorded, polarity corrected seismic signal recordings are time aligned. The time aligned recordings are summed. A most likely direction of motion and subvolume position are determined based on a selected attribute of the summed, time aligned seismic signals.

Abstract: Methods, systems, and software for representing seismic shot or receiver data as a superposition of a plurality of diplets are disclosed. The method includes decomposing one or more prestack shot or receiver records into a set of diplets, migrating the diplets using one or more velocity models, and synthesizing one or more migrated diplets into a migrated seismic volume, wherein each diplet comprises information about spatial location, orientation, amplitude, an associated wavelet, acquisition configuration, and coherency.

Abstract: Methods, systems and software for generating a multi-dimensional volume are disclosed. The methods include decomposing one or more original volumes into a collection of diplets, wherein each diplet comprises information about spatial location, orientation, amplitude, wavelet, acquisition configuration, and coherency. The methods further include migrating the collection of diplets using one or more of a velocity model or an anisotropic velocity model, and synthesizing one or more of the migrated diplets to an output multi-dimensional seismic volume.

Abstract: A method of investigating an underground formation underneath the earth's surface, comprising obtaining a first data set representing change in a predetermined seismic parameter over a period of time for a plurality of points in the underground formation, which first data set is derived from a time-lapse seismic survey of the earth formation spanning the period of time; obtaining a second data set representing geodetic deformation over substantially the same period of time at a plurality of locations on the earth's surface, which second data set is derived from a geodetic survey spanning the period of time; jointly processing the first and second data sets to obtain a map of a parameter related to volume change in the underground formation; wherein a geomechanical model of the underground formation is postulated; also a method of producing hydrocarbons and a computer program.

Abstract: A method is disclosed for combining seismic data sets. This method has application in merging data sets of different vintages, merging data sets collected using different acquisition technologies, and merging data sets acquired using different types of sensors, for example merging hydrophone and geophone measurements in ocean bottom seismic data.

Abstract: A calculated vertical velocity sensor signal is determined from a recorded pressure sensor signal. A constructed vertical velocity sensor signal is determined as a linear combination of the calculated vertical velocity sensor signal and a recorded vertical velocity sensor signal in dual-sensor seismic streamer data, using a mixture coefficient as a proportionality constant. An upgoing pressure wavefield component is determined as one half of a difference of the recorded pressure sensor signal and the constructed vertical velocity sensor signal, as a function of the mixture coefficient. An error in the upgoing pressure wavefield component is determined by propagating errors in the recorded pressure sensor signal and constructed vertical velocity sensor signal terms. A value of the mixture coefficient is determined that minimizes the error in the upgoing pressure wavefield component.