Abstract: System and method for analyzing seismic data from a formation. Stacked seismic data are provided, including a plurality of stack traces, e.g., by collecting seismic data from source and receiver locations and stacking the collected seismic data to produce the stacked seismic data. 3-dimensional (3-D) prestack traces are generated from the plurality of stack traces, e.g., by performing inverse moveout of stack traces, e.g., in a specified neighborhood, at common-depth-points, e.g., by inverse normal moveout, ray tracing, spike synthesis, etc. The inverse moveout corrected traces are convolved to compute predicted multiples which are useable in analyzing the formation. The multiples may be adaptively subtracted from the stacked seismic data, or optionally, from prestack data, to generate processed seismic data useable in analyzing the formation, e.g., for petroleum production potential.

Abstract: A method of combining directional seismic attributes using a supervised learning approach which may include extracting seismic information from acquired data in a direction along the spatial direction of a body of interest. The method is applicable both to onshore and offshore exploration and provides a more reliable means of detecting, separating and identifying geological features, for example gas chimneys, faults, layers, and any other type of geological objects with a spatial direction and shape. The method is also suited for the detection of reservoir changes by the use of time lapse seismic techniques.

Abstract: The present invention provides an improved method and apparatus for positioning seismic arrays. The method comprises determining a first position of an array, deploying the array, collecting inertial data at a plurality of points on the array once the array is at least partially deployed, and determining a second position of the array by augmenting the first position with the inertial data. The apparatus comprises a seismic array, an inertial sensor mounted on the seismic array and capable of gathering inertial data, and a computing device adapted to receive and analyze the inertial data to determine a position for the seismic array from the inertial data.

Abstract: A method for generating a model of a portion of the floor of a body of water from a plurality of depth measurement sources includes determining an overlap of any of the plurality of depth measurement sources with another depth measurement source and generating a relative shift between any two depth measurement sources that overlap. For each depth measurement source that overlaps with at least one other source, generating an overall shift based on the generated relative shifts. The method also includes generating a desired grid having a plurality of grid nodes and generating a model depth at a plurality of the grid nodes based, at least in part, on a global shift for the measurements of the plurality of sources based on the relative shift. Further, an output is generated of all model depths at respective grid nodes.

Abstract: An apparatus for monitoring a process comprises an acquisition means for repeatedly acquiring at least two different pieces of information of the process. A means for performing a component transformation uses the acquired information to calculate a main component measurement vector in a main component space. An evaluation means calculates a process indicator quantity by using the calculated main component measurement vector with one or several main component measurement vectors of a previous acquisition. Further, the evaluation means is formed to detect a process end by using the process indicator quantity.

Abstract: In one embodiment the invention comprises a system for utilizing a geologic time volume to investigate a portion of the earth in which a geologic time is selected and a search is made in the geologic time volume for locations having substantially the selected geologic time. Locations in the geologic time volume having substantially the geologic time are extracted from the geologic time volume. Locations having substantially the selected geologic time may be displayed to facilitate use of the geologic time volume by an interpreter.

Abstract: A method and apparatus for the detection and exploration of buried objects and hydrocarbons uses two separate signals having different frequency characteristics combined to enable interferometric analysis and imaging systems including radar, sonar, seismological, and general acoustical systems. The measurement and analysis of absorption and other elastic moduli are derived from a three-dimensional display of interferometric information. Interferometric holography also employs the unique characteristic record of frequency, phase, and amplitude of more than one signal.

Abstract: Methods, and models therefrom, to construct a 3-D polygonal model of a 3-D irregular volume within a GIS platform that include introducing data relating to the volume; estimating at least one 2-D polygon representing the volume's lateral boundary, estimating irregular surfaces representing the volume's top and bottom; clipping the estimated surfaces with the estimated 2-D polygon; constructing multipatches of a network of triangular panels or a grid of regularly spaced polylineZs; and joining the attributes to the model.

Abstract: A model seismic image of a subsurface seismic reflector is constructed, wherein a set of source and receiver pairs is located, and a subsurface velocity function is determined. Specular reflection points are determined on the subsurface seismic reflector for each of the source and receiver pairs. A Fresnel zone is determined on the subsurface seismic reflector for each of the specular reflection points, using the subsurface velocity function. One or more seismic wavelets are selected and a set of image points is defined containing the subsurface seismic reflector. A synthetic seismic amplitude is determined for each of the image points by summing the Fresnel zone synthetic seismic amplitude for all of the Fresnel zones that contain the image point, using the seismic wavelets. The model seismic image of the subsurface seismic reflector is constructed, using the synthetic seismic amplitudes at the image points.

Abstract: Methods of processing seismic data to remove unwanted noise from meaningful reflection signals are provided for. An offset weighting factor xn is applied to the amplitude data, wherein 0<n<1, and the offset weighted data is transformed from the offset-time domain to the time-slowness domain using a Radon transformation. A corrective filter is then applied to enhance the primary reflection signal content of the data and to eliminate unwanted noise events. After filtering, the enhanced signal content is inverse transformed from the time-slowness domain back to the offset-time domain using an inverse Radon transformation, and an inverse of the offset weighting factor pn is applied to the inverse transformed data, wherein 0<n<1.

Abstract: A method for determining the location and the orientation of the open natural fractures in an earth formation from the interaction of the two seismic signals, one signal transmitted into the formation from one wellbore and the second signal transmitted from the surface of the earth, the interaction of the two seismic signals as they simultaneously propagate through the fractured space is recorded in the second wellbore. The seismic signal transmitted from the surface is a lower frequency acoustic pulse of large amplitude identified as ‘modulation’ wave and the signal transmitted from the wellbore is a higher discrete frequency seismic signal, identified as ‘carrier’ wave. The interaction of the ‘carrier’ wave during the compression and rarefaction cycles of the ‘modulation’ signal is recorded.

Abstract: An automated system and method for developing an increased level of associate accountability in a production process by obtaining a performance projection from the associate, inputting this projection data into a computer system, obtaining and inputting actual performance data into the system and utilizing the system to compare the associate's projected performance to the associate's actual performance. The system and method of the present invention provides timely, objective and quantitative feedback to the production process associate. This feedback is subsequently used as a pay for performance incentive program.

Abstract: A product-sum operation portion for performing a product-sum operation (wavelet transformation) with respect to an input time-series signal by using as a base of integral a complex function in which the imaginary number portion is &pgr;/2 shifted in phase from the real number portion, a phase calculation portion for calculating a phase &thgr; from the ratio between the real number portion and the imaginary number portion of a result of the product-sum operation, a peak time detection portion for detecting a time point at which the calculated phase &thgr; changes from 2&pgr; to zero, as a peak time, are provided. Since the wavelet transformation is performed by using a basic wavelet function that is localized in terms of time and frequency, a peak time can be promptly detected. Furthermore, since a differential operation is not employed but the product-sum operation is performed, false detection caused by noises or the like can be prevented.

Abstract: This invention relates to mapping the open fractures in the reservoir subsurface formations. To map these open fractures, the elastically nonlinear interaction of the two surface generated seismic waves, as they propagate through the open fractures and are reflected back from the subsurface boundaries, is recorded using conventional 3-D seismic receiver configurations. Recorded data are processed for standard 3-D reflection imaging and additionally for mapping the location and orientation of the subsurface open fractures.

Abstract: The method of the present invention relates to the field of seismic data interpretation for the purpose of finding natural occurrences of oil and/or gas in a geophysical formation. The invention relates to a method of processing seismic geophysical data to produce time structure volumes. The method of the present invention is capable of displaying the position and orientation of layered rocks in the subsurface of the earth.

Abstract: A method and system is disclosed for interactively displaying estimated stability of rock surrounding a wellbore. The display shows a three-dimensional representation of the orientation of a portion of the wellbore and the associated estimation of stability of the rock surrounding the wellbore. The user can alter the orientation of the portion of the wellbore, after which in real time the stability estimation is recalculated and redisplayed. The method and system can be used for planning or modifying a well plan, either before or during the drilling process. The method and system can also be used for diagnosis of stability problems. The method and system can also be used for displaying and analyzing the estimated stability of perforations surrounding a wellbore and for planning and arranging such perforations.

Abstract: An improved system for designing seismic surveys wherein the density and areal size of the seismic survey components (e.g., sources or receivers) are selected based on a plurality of calculated templates of the components that are generated using a mapping function.

Abstract: A method of calculating reflection curvature in a seismic data volume wherein an apparent dip value is calculated in a first direction to generate a first apparent dip volume. A horizontal gradient is calculated in the first direction in the first apparent dip volume using a specified length scale to generate a first curvature volume. The process may be repeated one or more times, and the individual curvature volumes combined to generate a combined curvature volume for the seismic data volume.

Abstract: In one embodiment the invention comprises a system for planning a seismic survey based on a model of a subsurface formation in which a computer simulation is generated having sources and receivers positioned in selected locations with respect to the model. Ray tracing is performed from the sources to estimate a propagation ray path of seismic signals emanating from the source locations, and emergent points are determined at which ray paths reach the earth's surface following reflection from a subsurface area of interest. A survey may then be designed and performed in which receiver positions are concentrated at the areas where the emergent points are concentrated.

Abstract: A method for determination of seismic wave travel times from a surface location to at least one subsurface computation point (CP) within a plurality of subsurface location points. A velocity model of a region is defined. A complex monochromatic wavefield is computed, using the velocity model, for the at least one CP. An unwrapped phase of the seismic wave is determined at a neighboring computation point (NCP) proximate to at least one subsurface CP. The travel time of the seismic wave to the at least one CP is determined using the unwrapped NCP phase and the computed monochromatic wavefield for the at least one CP. Travel time maps and table may be created from the determined travel time values.

Abstract: The invention concerns a method for detecting geological discontinuity in an environment using an optical flow. The method includes the steps of selecting in the seismic block a section containing at least one discontinuity. The section constitutes a seismic image. The method includes computing a rough optical flow on the seismic image to obtain a first representation of an optical flow wherein the discontinuity constitutes a moving front. The method also includes smoothing, by a non-supervised dynamic cluster process, the optical flow representation so as to obtain a second optical flow representation wherein the discontinuity shows accentuated contrasts.

Abstract: A method for classification of a subsurface includes the steps of: inputting at least two seismic drive layer property data sets; inputting data defining one or more zones of interest in the classification input data sets; inputting analysis data sets with data types corresponding to that of the classification input data sets; inputting data defining a subset of interest in the analysis data sets; defining in the subset of interest within the data type space one or more data type subspaces that characterize subsurface features; selecting at least one data type subspace to be used for classification; determining which data points in the zone of interest fall within the selected data type subspaces; and typifying these data points to so classify these data points of the classification input data.

Abstract: A seismic processing system and method calculates a coherency estimate for a volume of seismic data to detect edges of seismic events. The method includes selecting a portion of the seismic data volume for analysis, selecting a spatial and temporal position in the subset seismic data volume, selecting a subset of seismic samples around seismic position, placing subset seismic sample volume in a matrix, or calculating cosine of instantaneous phase of subset of seismic samples and placing those samples in a matrix, and calculating a coherency estimate for that matrix. The coherency estimate is calculated using either eigenvalue, maximum likelihood or maximum entropy analysis. The coherency estimate is then written to a coherence seismic volume and another spatial and temporal seismic sample position is selected and the process is repeated until all coherence samples are computed for the seismic data volume. Finally, the coherence seismic data volume can be examined and analyzed for useful information.

Abstract: A method for forming a prograde kinematic model allowing reproduction in 3D intermediate geometries of geologic objects of an underground zone such as a sedimentary basin, from an initial state to a current state. A representation of the current geometry of the geologic objects of the zone is formed by interpretation of acquired data obtained by seismic exploration, by in-situ measurements and by observations, then each geologic object is subdivided into layers separated by deformation interfaces. Each one of the layers is defined by means of a grid pattern into a series of hexahedral volume elements. Tectonic deformations are then applied separately and successively to each series of volume elements of a layer in relation to an underlying layer while conserving the thickness and the surface area of an intermediate neutral surface in each volume element.

Abstract: An apparatus and method for combining a survey measurement dataset and a position dataset into a single dataset containing both measurement and position data is disclosed. The survey measurement data may be obtained from a ground penetrating radar, an inductometer, a magnetometer, or an optical camera. Positioning information is collected and merged with the survey information so that the position of the survey tool is known at each data point. Also provided are channel-equalization filters, spiking deconvolution filters, and frame filters that can be used in conjunction with the positioning information to enhance the quality of the images obtained from the data collected by the survey tool.

Abstract: The instant invention teaches an improved frequency domain based method of generating attributes from 2D or 3D seismic data. The central idea of the instant invention is that if a curve characterized by constant coefficients is fitted to a short-window Fourier transform amplitude or phase spectrum, the coefficient estimates that are obtained thereby can be used as seismic attributes for use in detecting changes in subsurface properties that may be associated with the generation, migration, accumulation, or presence of hydrocarbons. Since it is well known that many subsurface structural and stratigraphic features alter the frequency characteristics of seismic waveforms passing therethrough, the instant invention provides a new way to search through large numbers of seismic traces for frequency changes that may be correlated with subsurface features of exploration interest.

Abstract: An improved method for assessing the geologic risk for hydrocarbon presence and hydrocarbon accumulation size is disclosed. In one configuration, seismic attributes are assigned to a horizontal axis and data quality to a vertical axis to form a matrix crossplot. Direct Hydrocarbon Indicators (DHI) derived from seismic data are used to qualify the presence and accumulation size. A quantitative method for scaling and calibrating the DHI matrix is illustrated that can be applied to existing petroleum basins and by analog to frontier areas.

Abstract: In a three-dimensional exploring method for finding location of a buried object by transmitting a wave signal (4) by means of e.g.

Abstract: A method for recognizing and comparing features of attribute data expressed in a 3D data survey involves: extracting, mapping, color coding and displaying 3D data for at least one attribute. Preferably, the data is based on tomographic paths. The tomographic paths are defined within a subvolume of instantaneous attribute data having the shape of a sphere. This is accomplished by extracting the subvolume of attribute data having a desired shape, defining multiple tomographic paths extending from a point within the subvolume to its bounding surface, combining instantaneous attribute values encountered along each of the tomographic paths to determine multiple aggregate values, mapping the thus determined aggregate attribute values on the surface of the sphere using a color code, and displaying the color coded sphere. The attribute maps are correlated with preexisting geological or stratographic templates to identify features.

Abstract: Three substantially parallel surfaces are selected in a 3-D data volume and values of a seismic attribute on each of the three surfaces are encoded onto a Red-Green-Blue (RGB) color scale. A single display of this encoded data makes it possible to get a visualization of and interpret subtle structural and stratigraphic features of the 3-D data volume. The displayed seismic attribute may be the amplitude or one of many commonly used attributes. The 3-D data volume may be defined in terms of seismic times or in terms of seismic depths.

Abstract: A method and system for transferring synchronization data between a central control and seismic recording station and dependent stations in all the cases where the time of transmission through the connection channels between the elements may be liable to too great fluctuations is disclosed. The invention provides a central station (CCU) and intermediate local control and concentration stations (RRS), each connected to local acquisition units (RTU), with a common time reference or clock (H) (that can for example be provided by a satellite positioning network of a well-known type such as the GPS system, or based on the carrier frequency of a radio transmitter) which is picked up by specialized receivers associated with the elements of the seismic device, and in using this common reference to calculate the real transmission time and to local readjust seismic acquisition units (RTU).

Abstract: A system and method for viewing well log data is disclosed. A wellbore identifier is entered into a remote display device. The display device is at a first location separate from a facility operated by a well logging operator. The well identifier is transmitted to a first database having ancillary data therein. The first database is operated by the well logging operator. The ancillary data are sent to the first location, and the ancillary data and data recorded from a well logging instrument disposed in a wellbore are presented on the display device.

Abstract: A method, apparatus, and article of manufacture are provided that use measurement data to create a model of a subsurface area. The method includes creating an initial parameterized model having an initial estimate of model parameter uncertainties; considering measurement data from the subsurface area; updating the model and its associated uncertainty estimate; and repeating the considering and updating steps with additional measurement data. A computer-based apparatus and article of manufacture for implementing the method are also disclosed. The method, apparatus, and article of manufacture are particularly useful in assisting oil companies in making hydrocarbon reservoir data acquisition, drilling and field development decisions.

Abstract: A method of obtaining a representative 2D or 3D model of a heterogeneous medium described by multiple physical parameters (such as the impedances of the subsoil in relation to P or S type waves, its density, etc.) from various data. An a priori model with multiple parameters formed from known or estimated isolated values of the physical parameters and the initial model is improved by minimizing a global cost function representative, on the one hand, of the differences between synthetic records giving the response of the current model and the seismic records obtained, and on the other hand of the differences between the current model and the a priori model. These differences are measured in the sense of norms deduced from the a priori information on the uncertainties relative to the data and to the model, and the information can vary from one point of the model to another. The invention has an application for characterization of hydrocarbon reservoirs.

Abstract: Structural and stratigraphic discontinuities are identified in a 3-D volume of seismic data samples in the presence of reflection dip, by first selecting a primary and at least one secondary direction in the volume of seismic data samples. Next, skeleton patches are identified in the volume of seismic data samples, where the skeleton patches comprise groups of connected seismic samples representing seismic horizons in the volume of seismic data samples. Apparent dip is calculated in the primary and secondary directions at each data sample within the identified skeleton patches, creating a primary and secondary direction dip volumes, respectively, at corresponding data sample locations. A filter is applied to the primary direction dip and secondary direction dip volumes to fill in values at the data sample locations not within the identified skeleton patches.

Abstract: This invention relates to mapping the open fractures in the reservoir subsurface formations. To map these open fractures, the elastically nonlinear interaction of the two surface generated seismic waves, as they propagate through the open fractures and are reflected back from the subsurface boundaries, is recorded using conventional 3-D seismic receiver configurations. Recorded data are processed for standard 3-D reflection imaging and additionally for mapping the location and orientation of the subsurface open fractures.

Abstract: A system for, and method of, orienting seismic energy sources and seismic energy receivers to yield discriminated horizontal and vertical shear modes. In one embodiment, the system includes: (1) an initial matrix representing wave energy produced by a selected seismic energy source and received by a selected seismic energy receiver, (2) a first transforming matrix that cooperates with the initial matrix to orient the selected seismic energy source with respect to the selected seismic energy receiver and (3) a second transforming matrix that cooperates with the initial matrix to orient the selected seismic energy receiver with respect to the selected seismic energy source, the initial matrix thereby transformed into a successive matrix containing the discriminated horizontal and vertical shear modes.

Abstract: A seismic survey system having remote acquisition modules (RAMs) for acquiring seismic signals and communicating with a central recording system (CRU) via a network of cables, other RAMs, and line tap units (LTUs), arranged in a matrix of receiver lines and base lines. Each RAM cyclically converts analog signal values to digital, forming data packets. Interrogation commands emanating from the CRU and relayed with strategic delays by intervening LTUs and RAMs are received by the RAM. Each command causes the RAM to transmit a data packet. Strategic delays are set such that the transmission capacity of the line is best utilized. Power and frequency of transmission are selectable by the CRU to optimize performance. Cables contain multiple communication pairs. The network path between the RAM and the CRU is established from the CRU and altered in event of malfunction. All types of network elements are interconnectable. Recorded samples are synchronous.

Abstract: Permeability is one of the most important factors in influencing the commercial viability of a hydrocarbon reservoir. So far, permeability cannot be measured directly in-situ in reservoir formations. This invention relates to the field of estimating in-situ permeability of the reservoir rock formations. The measurements can be made across two wells or in a single well. Due to the morphology of their pore interconnections and the pore fluids in the rock, permeable rocks are elastically nonlinear. In a permeable rock, which is elastically nonlinear, the interactions between two elastic waves can be used in a unique way to map its physical properties. In this invention, the interaction of an elastic wave generated within the permeable rock with an externally generated seismic signal is used to determine the bulk tortuosity and bulk permeability of a reservoir rock formation.

Abstract: A method for constructing velocity models for stacking seismic data, or, more generally, a method for determining reflection geometries with seismic gathers through the use of trace-to-trace coherency coupled with global editing capability to separate velocity events corresponding to primary reflections from multiple reflections and other noise. A velocity model can be fit to the edited velocity events and used for stacking of seismic data. Alternatively, the measured reflection geometry has other potential uses including providing data to be input to a tomographic velocity updating procedure that produces a migration velocity model.

Abstract: A multi-trace geometric attribute of a regularly gridded surface is calculated at multiple scales, wherein, first, a window size is selected. Next, a set of the grid points is defined defining grid cells of the selected window size. Next, the geometric attribute is calculated using the traces at the set of the grid points. Next, the above selecting and calculating steps are repeated for sets of the grid points defining grid cells of different window sizes. Finally, the window size is determined whose calculations best represent the geometric attribute.

Abstract: Structural and stratigraphic discontinuities are identified in a 3-D volume of seismic data samples, by first selecting a plurality of directions containing a primary direction and at least one secondary direction. Next, one-dimensional, two-trace first discontinuity values are calculated along the primary direction for each seismic data sample in the 3-D data volume. Next, a series of sequentially less restrictive thresholds is defined, such that a significant portion, preferably at least approximately 10%, of the first discontinuity values satisfy the first threshold. This significant portion of first discontinuity values is then stored in an output discontinuity volume at the corresponding sample locations. The following steps are repeated for each remaining data sample until that sample has a value stored at the corresponding sample location in the output discontinuity volume.

Abstract: A process for constructing a three-dimensional geologic model of a subsurface earth volume in which the positions of geologic interfaces within the model are adjusted as the model is being constructed. The resulting geologic model should be consistent with all available geologic and geophysical information regarding the subsurface earth volume, including information regarding the spatial attributes of geologic interfaces within said subsurface earth volume.

Abstract: A method of processing seismic data comprising obtaining a seismic data volume covering a predetermined volume of earth; determining for each voxel in the seismic data volume the local orientation of the seismic data; determining for each voxel whether there is an edge in its neighborhood; and carrying out a smoothing operation on each voxel in the seismic data volume, wherein the direction of the smoothing operation is the local orientation of the data and wherein the smoothing operation does not go over the edge, to obtain a processed seismic data volume in which the quantity assigned to each voxel in the processed data volume is the result obtained by carrying out the smoothing operation in that voxel in the seismic data volume.

Abstract: A method and apparatus for low-power sensing and processing are provided. A method preferably includes collecting a plurality of sensor signals. The plurality of sensors include sensed data representative of at least shock and vibration. The method also includes converting the plurality of sensor signals into digital data, processing the digital data, generating a data communications protocol for communicating the digital data, and simultaneously and remotely detecting the generated communications protocol having the processed data to determined the occurrence of at least one predetermined condition. An apparatus preferably includes a low-power, data acquisition processing circuit responsive to a plurality of sensor signals representative of at least shock and vibration for acquiring and processing the sensed data.

Abstract: A seismic survey area is divided into a number of “bins” of a convenient shape and size. The data from the suite of shot and receiver positions are analyzed and all shot-receiver pairs that have a common sort point (CSP) are assigned to the spatial bin in which the CSP is located. The CSP maybe a common mid-point (CMP). The data within each bin are analyzed to give a figure of merit of the adequacy of the sampling for each bin. These figures of merit are displayed in a color display that makes the inadequacies of the sampling apparent, making it possible to modify the planned acquisition geometry prior to the actual deployment of the receiver lines. Alternatively, a figure of merit is determined for the overall survey.

Abstract: In accordance with the present invention, there is disclosed herein a method of seismic interpretation that is designed to improve the quality and speed with which an explorationist can pick and interpret a seismic section or volume. The instant invention utilizes unseeded picking to create a collection of patches or areas of similar-character reflector picks. The method is unsupervised initially and builds an output database that preferably contains the time and amplitude of each “assigned” event, an assigned event being a seismic reflection that is determined to be similar in some sense to its neighboring traces. Then, during subsequent interpretation the explorationist quickly builds an interpretation by utilizing and selecting from the pre-assembled collections of similar traces stored in the database.

Abstract: Method of producing impact point position probability maps for a well. It consists in defining a fixed, invariant target point chosen a priori on an initial location E0 of the surface S, discretizing the surface S with the aid of a grid composed of nodes and of grid cells, assigning at least one elementary geometrical uncertainty vector to each node of the grid of the surface S, determining a statistically significant number of occurrences of locations of the surface S as a function of the geometrical uncertainties affecting it, projecting the target point onto each occurrence of location of the surface so as to deduce a point of impact therefrom, transferring the set of impact points onto the location E0 of the surface S by allocating, to each of these points, surface co-ordinates identical to those which it had on the occurrence of location of the surface containing it.

Abstract: A method for processing of seismic data traces utilizes the fact that a series of linear operations applied to vectors can be approximated by application of the linear operations to a set of basis vectors which are then scaled and summed. The method is applied to seismic data traces with a reduction in processing time provided that computation time in creating the basis vectors is small relative to the total computation time in applying the method. Theoretically there is much to be gained in terms of processing speed by implementation of this method on a vector processor that is designed to do multiply and accumulate operations quickly.

Abstract: A method, a map and an article of manufacture for the exploration of hydrocarbons. In one embodiment of the invention, the method comprises the steps of: accessing 3D seismic data; dividing the data into an array of relatively small three-dimensional cells; determining in each cell the semblance/similarity, the dip and dip azimuth of the seismic traces contained therein; and displaying dip, dip azimuth and the semblance/similarity of each cell in the form a two-dimensional map. In one embodiment, semblance/similarity is a function of time, the number of seismic traces within the cell, and the apparent dip and apparent dip azimuth of the traces within the cell; the semblance/similarity of a cell is determined by making a plurality of measurements of the semblance/similarity of the traces within the cell and selecting the largest of the measurements.