For Dip Patents (Class 367/53)
  • Patent number: 10365403
    Abstract: A modified direct search Neighborhood Algorithm (NA), similar to genetic or evolutionary algorithms, is used for automatic calibration of Stratigraphic Forward Models (SFM) to data constraints. The modified NA comprises explicit escape clauses from local minima and admissible solutions, thereby preventing a natural tendency of conventional NAs to converge and oversample a single minimum. The density of models in parameter space is used to define local minima. Admissible solutions are defined by considering error thresholds taking into account that SFM may be imperfect and that calibration constraints may be uncertain. The modified NA algorithm obtains a plurality of geological scenarios that agree with the data, and which can be used for further analysis and prediction.
    Type: Grant
    Filed: December 19, 2012
    Date of Patent: July 30, 2019
    Assignee: SHELL OIL COMPANY
    Inventors: Oriol Falivene Aldea, Stéphane Youri Richard Michael Joachim Gesbert, James Cecil Pickens
  • Patent number: 10324204
    Abstract: In some embodiments, a seismic processing method comprises assembling a specularity gather by determining a specularity value at each of a plurality of subsurface locations, and summing trace amplitudes into a plurality of bins, each bin characterized by a range of specularity values. The specularity value at a subsurface location is computed according to an angle between a normal to a local reflector and a direction of a total (source+receiver) traveltime gradient. For example, the specularity may be proportional to (e.g. equal to) a magnitude of the cosine of the angle. A diffraction image may be generated by summing specularity gather data over specularity, with specular event amplitudes attenuated relative to diffractive event amplitudes.
    Type: Grant
    Filed: July 21, 2014
    Date of Patent: June 18, 2019
    Assignee: Z TERRA INC.
    Inventors: Ioan Sturzu, Alexander M. Popovici, Tijmen J. Moser, Iulian F. Musat, Nicolay Tanushev
  • Patent number: 10310117
    Abstract: A method for generating seismic attribute gathers, the method including: computing, with a computer, seismic images with a field dataset; generating, with a computer, synthetic data corresponding to the seismic images; computing, with a computer, an attribute volume by applying an expectation method to the synthetic data; mapping, with a computer, the attribute volume to the seismic images; and generating, with a computer, seismic attribute gathers by stacking the seismic images mapped to the attribute volume.
    Type: Grant
    Filed: January 17, 2017
    Date of Patent: June 4, 2019
    Assignee: ExxonMobil Upstream Research Company
    Inventors: Jia Yan, John E. Anderson, Rongrong Lu, Carey M. Marcinkovich
  • Patent number: 10224900
    Abstract: Systems and methods are provided for de-noising seismic data recorded by seismic receivers. A first portion of the seismic data having a first signal-to-noise ratio (SNR) to is processed to generate a de-noising operator or function. The de-noising operator is applied to a second portion of seismic data having a second SNR to remove noise from the second portion of the seismic data, where the first SNR is greater than the second SNR.
    Type: Grant
    Filed: June 6, 2014
    Date of Patent: March 5, 2019
    Assignee: CGG SERVICE SAS
    Inventors: Gordon Poole, Richard Winnett
  • Patent number: 10145973
    Abstract: Embodiments of the invention provide a method for classifying seismic attributes, including generating data points by cross plotting seismic attributes from a first data volume and a second data volume, encompassing at least one of the generated data points within a polygon, generating a reference line, determining an interpolation direction relative to the reference line, and assigning an attribute value to the at least one generated data point encompassed within the polygon wherein the assigned attribute value is interpolated based on the combination of its position to the reference line along the interpolation direction and the shape of the polygon.
    Type: Grant
    Filed: November 27, 2013
    Date of Patent: December 4, 2018
    Assignee: Landmark Graphics Corporation
    Inventors: Nam X. Nguyen, Eugene C. Heinrichs, Jocelyn Chan
  • Patent number: 9865097
    Abstract: Systems and methods for identifying matching properties between a group of bodies representing a geological structure and a table of properties by performing property matching on the group of bodies to convert each body to a respective compartment represented by a triangulated mesh of the bounding body.
    Type: Grant
    Filed: August 15, 2014
    Date of Patent: January 9, 2018
    Assignee: LANDMARK GRAPHICS CORPORATION
    Inventors: Michael David Ewing, Sammi Igarashi
  • Patent number: 9753165
    Abstract: Embodiments of a system are provided for forming enhanced seismic array traces using virtual seismic sensors in addition to the real seismic sensors to form a virtual seismic array. The system receives the signal responses from the real sensors, processes the signal responses from the sensors to define virtual signals using a narrowband decomposition of the complex envelope of the sensor signal responses, calculates second- and fourth-order statistics to derive steering vectors for the array of real sensors, and forms a virtual seismic array in response thereto. Machines, computer program product, and computer-implemented methods are provided for forming enhanced seismic array traces by receiving the array responses from sensors, processing the signals to define virtual sensor signals and a virtual seismic array, and forming an array response for the virtual seismic array to form a seismic trace of enhanced resolution.
    Type: Grant
    Filed: December 28, 2015
    Date of Patent: September 5, 2017
    Assignees: Saudi Arabian Oil Company, The Texas A&M University System
    Inventors: Ibrahim Abdulaziz Alhukail, Luc Ikelle
  • Patent number: 9651694
    Abstract: According to one embodiment, subsurface ray directions in beam migration or subsurface wave propagation directions in reverse time migrations are used to obtain additional Specular Filter (SF) and Dip Oriented Partial Imaging (DOPI) images. SF migration applies a specular imaging condition during migration with a pre-specified subsurface dip field. It boosts the S/N ratio in both images and gathers, by effectively removing migration noise. DOPI images are produced by decomposing a standard migration image according to subsurface dip inclination or/and dip azimuth groups, providing various views of the subsurface image. Both SF and DOPI migration images can supply valuable additional information compared to a standard migration image, and they can be efficiently generated during migration.
    Type: Grant
    Filed: March 31, 2014
    Date of Patent: May 16, 2017
    Assignee: BP CORPORATION NORTH AMERICA INC.
    Inventor: Qie Zhang
  • Patent number: 9453930
    Abstract: This disclosure presents computational systems and methods for obtaining high-resolution, three-dimensional seismic images of a region of a subterranean formation using separated up-going and down-going wavefields that include primary and multiple reflections obtained by processing dual-sensor towed streamer seismic data. The inclusion of multiple reflections reduces acquisition footprints in migration of the seismic data. The computational systems and methods produce high-resolution images in a region of a subterranean formation that lies below a body of water. The methods and systems employ a digitally encoded wavefields constructed from a discrete sampling of a two-dimensional slice of a three-dimensional wavefield and stored in one or more tangible, physical data-storage devices.
    Type: Grant
    Filed: October 2, 2013
    Date of Patent: September 27, 2016
    Assignee: PGS GEOPHYSICAL AS
    Inventors: Norman Daniel Whitmore, Jr., Shaoping Lu
  • Patent number: 9217803
    Abstract: Computing device and method for calculating time-shifts associated with travel-times of seismic waves emitted by a source and recorded by plural seismic detectors after reflection from a subsurface structure. The method includes receiving seismic data (d) that includes plural traces related to a subsurface, wherein the seismic data (d) is in a time-space domain; transforming with a processor the seismic data (d) from the time-space domain to a radon domain; picking linear events from the seismic data in the radon domain; calculating the time-shifts associated with the picked linear events; correcting the seismic data (d) based on the time-shifts to obtain new seismic data (d?); and computing an image of the subsurface based on the new seismic data (d?). The time-shifts are calculated per trace and per event.
    Type: Grant
    Filed: January 11, 2013
    Date of Patent: December 22, 2015
    Assignee: CGGVERITAS SERVICES SA
    Inventor: Pierre Hugonnet
  • Patent number: 9188689
    Abstract: Computing systems and methods to producing a reverse time migration model dip-guided image using processed vertical seismic profile data are provided. In one embodiment, vertical seismic profile data for a subsurface geological formation is obtained. One or more dip estimates corresponding to the subsurface geological formation are also obtained. One or more model dip-guided reverse time migration imaging conditions are determined and applied to the obtained vertical seismic profile data to produce the processed vertical seismic profile data.
    Type: Grant
    Filed: December 21, 2012
    Date of Patent: November 17, 2015
    Assignee: WesternGeco L.L.C.
    Inventors: Kui Lin, Igor Borodin, Leonid Dovgilovich, Vasily Baydin, Ivan Sofronov
  • Patent number: 9075160
    Abstract: To perform inversion to produce a model of a structure, a filtering operator based at least on an angle between a propagating direction of a source wavefield and a propagating direction of a back-propagated receiver wavefield is computed. The filtering operator is used in performing the inversion to produce the model of the structure.
    Type: Grant
    Filed: May 3, 2012
    Date of Patent: July 7, 2015
    Assignee: Schlumberger Technology Corporation
    Inventors: Paul N. Childs, Robin Fletcher, Xiang Du, Eugene William Starr
  • Patent number: 9030909
    Abstract: A method of conducting a seismic survey of an area including a region of high seismic velocity regimes in a shallow overburden. According to the method, a zone is identified in which the boundary of the high seismic velocity region has a substantially constant critical angle and a course is plotted through the identified zone. A zone based directional seismic source is applied sequentially, with a directivity angle equal to or close to the measured critical angle. The response is detected using receivers.
    Type: Grant
    Filed: February 6, 2007
    Date of Patent: May 12, 2015
    Assignee: Statoil Petroleum AS
    Inventors: Kai Hogstad, Bente Fotland, Constantin Gerea
  • Patent number: 8948463
    Abstract: A method for analyzing seismic data by generating a post-migration common image gather in a dip angle domain from measured seismic data; detecting concave features related to reflection events in the common image gather and apexes; filtering out part of the concave features in the common image gather in a vicinity of the detected apexes; applying a hybrid Radon transform to the filtered common image gather to separate residues of the concave features from other image features related to diffraction events; and applying an inverse hybrid Radon transform to an image containing the separated features related to diffraction events to obtain a transformed common image gather in the dip angle domain.
    Type: Grant
    Filed: June 7, 2010
    Date of Patent: February 3, 2015
    Assignee: Total SA
    Inventors: Evgeny Landa, Reda Baina
  • Patent number: 8913460
    Abstract: A disclosed example method includes providing, in a borehole, a transmitter (Tx) and receivers (Rxs) spaced linearly from Tx at known distances, measuring linear propagation times (LPts) for a signal to propagate from Tx to each of Rxs, determining an inline velocity (VINL) based on LPts, measuring reflection times (Rts) for a signal to propagate from Tx to each of the Rxs via a boundary, for each of Rts, providing a time-distance anisotropic velocity (TDAV) relationship depending on an effective signal velocity (ESV) in an anisotropic formation adjacent the boundary as a function of reflection angle for the reflection time signal to the boundary, VINL and orthogonal velocity, performing semblance processing to combine the TDAV relationships with VINL for a best-fit calculation of the ESVs for the different reflection angles of the reflection time signals, and calculating a distance for the corresponding receiver to the boundary on the calculation.
    Type: Grant
    Filed: August 17, 2012
    Date of Patent: December 16, 2014
    Assignee: Schlumberger Technology Corporation
    Inventors: Vivian Pistre, Jakob Brandt Utne Haldorsen
  • Patent number: 8902702
    Abstract: Methods of and apparatus to image one or more subsurface formation features are disclosed. An example method includes generating acoustic waves with a transmitter and receiving the acoustic waves and acoustic data contained therein at one or more receivers. The example method also includes extracting one or more S-S, P-S or S-P reflected waveform data from the acoustic data, estimating a dip of the one or more subsurface formation features, migrating the one or more S-S, P-S or S-P reflected waveform data with the estimated dip and mapping the migrated one or more S-S, P-S or S-P reflected waveform data. In addition, the example method includes identifying one or more permeable subsurface formation features using the mapped migrated one or more S-S, P-S or S-P reflected waveform data.
    Type: Grant
    Filed: April 15, 2011
    Date of Patent: December 2, 2014
    Assignee: Schlumberger Technology Corporation
    Inventors: Nobuyasu Hirabayashi, Kentaro Torii, Hiroaki Yamamoto, Jakob Haldorsen, Arne Voskamp
  • Patent number: 8902708
    Abstract: Seismic data representing the propagation of seismic energy through a geologic volume of interest is processed. The seismic energy propagates through the geologic volume of interest from one or more source locations at or near the geologic volume of interest to one or more detector locations at or near the geologic volume of interest. In processing the seismic data, the seismic energy is modeled as beams (e.g., Gaussian beams). The processing performed (i) corrects for misalignment of the one or more source locations and/or the one or more detector locations with a regular, predetermined mesh, and (ii) steers the seismic data based on the modeled beams.
    Type: Grant
    Filed: November 5, 2009
    Date of Patent: December 2, 2014
    Assignee: Chevron U.S.A. Inc.
    Inventors: Norman Ross Hill, Yue Wang
  • Publication number: 20140293744
    Abstract: According to one embodiment, subsurface ray directions in beam migration or subsurface wave propagation directions in reverse time migrations are used to obtain additional Specular Filter (SF) and Dip Oriented Partial Imaging (DOPI) images. SF migration applies a specular imaging condition during migration with a pre-specified subsurface dip field. It boosts the S/N ratio in both images and gathers, by effectively removing migration noise. DOPI images are produced by decomposing a standard migration image according to subsurface dip inclination or/and dip azimuth groups, providing various views of the subsurface image. Both SF and DOPI migration images can supply valuable additional information compared to a standard migration image, and they can be efficiently generated during migration.
    Type: Application
    Filed: March 31, 2014
    Publication date: October 2, 2014
    Applicant: BP CORPORATION NORTH AMERICA INC.
    Inventor: QIE ZHANG
  • Publication number: 20140185413
    Abstract: A method can include receiving a request for a dip value for a location within a sub-surface volume; responsive to the request, locating complimentary dip values for locations within the sub-surface volume where the location for the requested dip value lies within bounds defined by the locations for the complimentary dips values; and interpolating a value for the requested dip value based on the complimentary dip values. Various other apparatuses, systems, methods, etc., are also disclosed.
    Type: Application
    Filed: January 2, 2013
    Publication date: July 3, 2014
    Applicant: SCHLUMBERGER TECHNOLOGY CORPORATION
    Inventor: Victor Aarre
  • Patent number: 8760967
    Abstract: A technique includes processing first data indicative of a first image of a subsurface region of interest on a machine to generate second data indicative of a second image. The first image is derived from measurements of seismic waves, which propagate in a plurality of directions, and the second image is generated by partitioning the first image based on the directions. The technique includes processing the second data to determine a dip decomposition for each of the directions; and based on the dip decompositions and the directions, generating an angle domain common image gather.
    Type: Grant
    Filed: April 6, 2011
    Date of Patent: June 24, 2014
    Assignee: WesternGeco L.L.C.
    Inventors: David E. Nichols, Madhav Vyas, Everett C. Mobley
  • Publication number: 20140133275
    Abstract: The process of obtaining seismic data includes deploying a seismic energy source and seismic receivers, actuating the source, and detecting seismic energy resulting therefrom at the receivers. The process further includes digitally sampling seismic energy detected at the receivers indexed with respect to time to form a plurality of traces and sorting the traces to form a plurality of shot gathers. In addition, the process includes applying a depth migration technique to the shot gathers to generate two images according to the cross-correlation imaging condition (I0) and the gradient-based imaging condition (I1) for each shot gather. A reflection angle (?) or a general domain parameter (?) is computed at each subsurface position and the images are mapped according to the corresponding reflection angle or the general domain parameter to form common image gathers. Amplitude correction is applied to common image gathers and the images and common image gathers are stored on non-transitory computer-readable media.
    Type: Application
    Filed: November 13, 2012
    Publication date: May 15, 2014
    Applicant: TOTAL E&P USA, INC.
    Inventors: Huimin Guan, Paul Williamson, Francois Audebert, Bertrand Duquet, Bertrand Denel
  • Publication number: 20140133273
    Abstract: Refracted energy travel time can help to derive anisotropic parameters in a target layer. These anisotropic parameters allow us to both explore for new reservoirs and to understand stress and fracturing in existing reservoirs. This information can be used to i) detect oil reservoirs, ii) spot naturally fractured, hence high production zones, iii) detect dominant natural stress directions, iv) better place horizontal wells to optimize production, v) monitoring man made fractures or induced directional stress changes. The method is demonstrated using synthetic and real data.
    Type: Application
    Filed: February 21, 2013
    Publication date: May 15, 2014
    Applicant: CONOCOPHILLIPS COMPANY
    Inventors: Samik SIL, Ali TURA, Roman KAZINNIK, Xinfa ZHU
  • Patent number: 8694262
    Abstract: A system and method for subsurface characterization including depth and structural uncertainty estimation is disclosed. In one embodiment, the method may include determining a detectability threshold for moveout in a seismic data gather based on the seismic data and computing a depth uncertainty function, wherein the depth uncertainty function represents an error estimate that is used to analyze an interpretation of the seismic data. In another embodiment, the method may include receiving a depth uncertainty volume and at least one interpreted horizon from seismic data, extracting a depth uncertainty cage for each of the interpreted horizons based on the depth uncertainty volume, and simulating multiple realizations for each of the interpreted horizons, constrained by the depth uncertainty cage. The multiple realizations may be used for analyzing changes to geometrical or structural properties of the at least one interpreted horizon.
    Type: Grant
    Filed: August 15, 2011
    Date of Patent: April 8, 2014
    Assignee: Chevron U.S.A. Inc.
    Inventors: Philip Stephan Schultz, Cory James Hoelting
  • Publication number: 20140086011
    Abstract: A method for displaying exploration and production (E&P) data set during an E&P tool session of a field having a subterranean formation. The method includes generating, by an E&P tool executing on a computer processor during the E&P tool session, an E&P data set based on a subterranean formation field data set, displaying, to a user controlling the E&P tool session, the E&P data set as a multi-dimensional canvas, generating, by the computer processor and in response to a user input identifying a point in the multi-dimensional canvas, a strike&dip tool tip, and further displaying the strike&dip tool tip superimposing the multi-dimensional canvas, wherein the strike&dip tool tip is tagged to the point in the multi-dimensional canvas.
    Type: Application
    Filed: September 25, 2013
    Publication date: March 27, 2014
    Applicant: Schlumberger Technology Corporation
    Inventor: Walter Emerson Brown
  • Patent number: 8614578
    Abstract: The present disclosure relates to determining the attenuation of an electromagnetic signal passing through a conductive material. An antenna is provided and placed in relatively close proximity to the conductive material. An alternating current is passed through the antenna and the impedance of the antenna is measured. The attenuation is determined using the measured impedance. A single frequency measurement may be made, or multiple measurements using different frequencies may be made. Grouped parameters based on properties of the material and the frequency of the current are used to relate the coil impedance to the attenuation. A current frequency for which the ratio of the antenna's resistive part of the impedance to the angular frequency of the current is substantially insensitive to at least one of the parameters is preferred.
    Type: Grant
    Filed: December 18, 2009
    Date of Patent: December 24, 2013
    Assignee: Schlumberger Technology Corporation
    Inventors: Guozhong Gao, H. Frank Morrison, Hong Zhang, Richard A. Rosthal, David Alumbaugh, Cyrille Levesque
  • Publication number: 20130242699
    Abstract: There is a method of seismic data processing that includes receiving seismic data that includes a set of seismic traces, each trace including a signal recorded by a sensor after having been propagated in a subsurface area; migrating the seismic data according to a first velocity model; picking from the time-migrated seismic data one or more events corresponding to one or more subsurface reflectors so as to obtain a set of facets locally approximating the event; kinematic demigrating the picked set of facets so as to obtain simplified seismic data that includes the set of facets and a set of attributes associated with the set of facets; migrating the set of facets based on a second velocity model; and updating the initial velocity model based on an alignment of migrated points within the set of facets.
    Type: Application
    Filed: April 23, 2013
    Publication date: September 19, 2013
    Applicant: CGGVERITAS SERVICES SA
    Inventors: Gilles LAMBARE, Jean-Paul TOURE, Ziqin YU
  • Publication number: 20130182538
    Abstract: Computing systems and methods to producing a reverse time migration model dip-guided image using processed vertical seismic profile data are provided. In one embodiment, vertical seismic profile data for a subsurface geological formation is obtained. One or more dip estimates corresponding to the subsurface geological formation are also obtained. One or more model dip-guided reverse time migration imaging conditions are determined and applied to the obtained vertical seismic profile data to produce the processed vertical seismic profile data.
    Type: Application
    Filed: December 21, 2012
    Publication date: July 18, 2013
    Applicant: WESTERNGECO L.L.C.
    Inventor: WESTERNGECO L.L.C.
  • Patent number: 8478531
    Abstract: A best fitting trace in seismic data is determined for a desired trace to be reconstructed. A dip-based correction is calculated per trace and per sample for differences in azimuth, common midpoint coordinates, and offset between the best fitting trace and the desired trace. The dip-based correction is applied to the best fitting trace to reconstruct the desired trace for 3D surface-related multiple prediction.
    Type: Grant
    Filed: April 7, 2010
    Date of Patent: July 2, 2013
    Assignee: PGS Geophysical AS
    Inventors: Peter A. Aaron, Roald G. van Borselen, Robertus F. Hegge, Simon R. Barnes
  • Publication number: 20130155813
    Abstract: An iterative dip-steering median filter is provided for random noise attenuation in seismic data where conflicting dips are indicated in the data. A number of dominant dips inside a processing window or sample of the data are identified by a Fourier-radial transform in the frequency-wavenumber domain. A median filter is then applied along the dominant dip to remove noise, and the remaining signal after filtering is retained for further median filter iterations. Iterations are repeated to apply the median filter along the most dominant dip in the remaining data. The processing continues in subsequent iterations until all selected dips have been processed. The remaining signal of each iteration is then summed for final output.
    Type: Application
    Filed: December 14, 2012
    Publication date: June 20, 2013
    Applicant: Saudi Arabian Oil Company
    Inventor: Saudi Arabian Oil Company
  • Publication number: 20130100771
    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.
    Type: Application
    Filed: June 26, 2012
    Publication date: April 25, 2013
    Inventors: Mamadou S. Diallo, Warren S. Ross
  • Publication number: 20120320712
    Abstract: A method can include, within a neighborhood, selecting a sample seismic trace and neighboring seismic traces, individually time shifting each of the neighboring seismic traces with respect to the sample seismic trace to determine a set of individual time shift values that correspond to individual maximum cross correlation values for each of the neighboring seismic traces with respect to the sample seismic trace, determining series of inline direction and crossline direction first derivative values for the set of time shift values, determining an inline average dip value and a crossline average dip value based on the series of first derivative values, and storing to a memory storage device, coordinates for the sample seismic trace, the inline average dip value, and the crossline average dip value. Various other apparatuses, systems, methods, etc., are also disclosed.
    Type: Application
    Filed: June 12, 2012
    Publication date: December 20, 2012
    Inventors: Ahmed Adnan Aqrawi, Trond Hellem Bø
  • Publication number: 20120307593
    Abstract: Device and method for estimating an event-related main anisotropy axis for a volume in a subsurface. The method includes selecting a velocity migration model for the given volume of the subsurface; receiving seismic data for the given volume; migrating the seismic data based on the velocity migration model; picking locally coherent events from the migrated data; and performing a tomographic process based on invariants to calculate the event-related main anisotropy axis.
    Type: Application
    Filed: May 29, 2012
    Publication date: December 6, 2012
    Applicant: CGGVERITAS SERVICES SA
    Inventor: Patrice GUILLAUME
  • Patent number: 8326542
    Abstract: A computer implemented method for retrieving seismic data from a seismic section provided in a bitmap format. The method includes reconstructing a two dimensional matrix of seismic interpolated data in which a value at a given pixel in the matrix is proportional to local density of wiggles in the seismic section with an added value of a previously calculated pixel. The method may be implemented in either of computer hardware configured to perform said method and computer software embodied in a non-transitory, tangible, computer-readable storage medium. Also disclosed are corresponding computer program product and data processing system.
    Type: Grant
    Filed: November 19, 2009
    Date of Patent: December 4, 2012
    Assignee: International Business Machines Corporation
    Inventors: Dan Shmuel Chevion, Yaacov Navon
  • Publication number: 20120275268
    Abstract: Computer instructions, computing device and method for processing seismic data under-sampled in an angle domain, the seismic data corresponding to a reverse time migration, three-dimensional, angle domain common image gather (ADCIG). The method includes receiving the seismic data; calculating, based on the seismic data, shot and receiver wave-fields with an RTM wave propagation engine; applying a wave-fields decomposition algorithm to obtain a propagation direction for the shot and receiver wave-fields; forming the ADCIG by applying an image condition to the shot and receiver wave-fields; determining that specular energies of the ADCIG are under-sampled around a reflection angle; during the step of forming the ADCIG, extrapolating the specular energies to a neighborhood of the reflection angle; and generating an image of a subsurface that is being surveyed based on the extrapolated specular energies.
    Type: Application
    Filed: April 24, 2012
    Publication date: November 1, 2012
    Applicant: CGGVERITAS SERVICES SA
    Inventors: Bing TANG, Sheng XU, Yu ZHANG
  • Patent number: 8300498
    Abstract: Dips are calculated for a series of sets of adjacent multiple contribution traces, from seismic data representative of subsurface formations, in the vicinity of a boundary of an aperture of a multiple contribution gather, the seismic data acquired by deploying a plurality of seismic sensors proximate an area of the earth's subsurface to be evaluated, the seismic sensors generating at least one of an electrical and optical signal in response to seismic energy. The boundary of the aperture of the multiple contribution gather is recursively extended, based on the calculated dips. Multiple contribution traces in the multiple contribution gather with the extended aperture boundary are stacked to generate predicted multiple traces. The predicted multiple traces are subtracted from the seismic data to generate surface-related multiple attenuated data useful for imaging the subsurface formations.
    Type: Grant
    Filed: June 30, 2009
    Date of Patent: October 30, 2012
    Assignee: PGS Geophysical AS
    Inventors: Robertus F. Hegge, Roald G. van Borselen
  • Patent number: 8301385
    Abstract: Beamed data can be obtained from shot gather data, and debeamed data can be obtained from beamed data. Shot gather data for a geophysical volume of interest in a first domain and/or beamed data in a third domain may be received. The first domain has a component relating to seismic wave propagation time and a spatial component relating to lateral spacing. The third domain has a component relating to local plane wave arrival time at a beam center surface location and a component relating to plane wave arrival directions. Data may be transformed between the first domain and a second domain. The second domain has a frequency component and a spatial component corresponding to the spatial component of the first domain. A forward or reverse transform may be applied to transform shot gather data in the first domain to/from beamed data in the third domain.
    Type: Grant
    Filed: June 29, 2010
    Date of Patent: October 30, 2012
    Assignee: Chevron U.S.A. Inc.
    Inventors: Chaoshun Hu, Yue Wang, Tamas Nemeth
  • Publication number: 20120271550
    Abstract: Seismic survey data is converted into a subsurface data volume that users can view to understand and analyze the subsurface structures in the survey region. At least some of the disclosed systems and methods employ three-dimensional reverse time migration using wave equations adapted for use in formations having tilted transverse isotropy. Relative to existing methods, the disclosed systems and methods rely on fewer approximations and suffer fewer limitations on the circumstances in which they can be employed. Moreover, because the disclosed wave equations are derived from Hooke's law (and consequently they operate on fields that are directly tied to physical quantities), they demonstrate an increased stability relative to existing methods. Survey data analysts employing the disclosed systems and methods should obtain better images of the subsurface and be better able to identify reservoirs and deposits for commercial exploitation.
    Type: Application
    Filed: November 2, 2009
    Publication date: October 25, 2012
    Applicant: LANDMARK GRAPHICS CORPORATION
    Inventors: Fan Jiang, Shengwen Jin
  • Publication number: 20120257477
    Abstract: A method for visualizing seismic data of a subterranean formation, including obtaining an estimated dip field of the subterranean formation, wherein the estimated dip field represents a measure of deviation of a stratigraphic layer from flat, extracting a matrix data item surrounding a voxel of the seismic data, wherein the matrix data item is extracted from the seismic data based on a value of the estimated dip field surrounding the voxel, generating modified seismic data by at least applying a matrix operator to the seismic data, wherein the matrix operator calculates a partial derivative of the seismic data using the matrix data item, and displaying the modified seismic data.
    Type: Application
    Filed: April 3, 2012
    Publication date: October 11, 2012
    Inventors: Ahmed Adnan Aqrawi, Trond Hellem Bø
  • Patent number: 8233351
    Abstract: A system and method for locating subsurface diffractors. The method operates on two-dimensional (2-D) seismic data that includes one or more 2-D seismic lines. The 2-D seismic data may be preprocessed to enhance diffracted energy. For each hypothetical diffractor location in a set of hypothetical diffractor locations, the method involves analyzing at least a subset of the seismic traces of the one or more 2-D seismic lines, in order to compute a value indicating an extent to which those seismic traces contain diffraction arrivals consistent with the hypothetical diffractor location. The method may further involve generating, storing and displaying an image (or map) based on the computed values. The image may illustrate areas of high, intermediate and low diffraction, and may be used to assess the formation.
    Type: Grant
    Filed: August 26, 2011
    Date of Patent: July 31, 2012
    Assignee: Landmark Graphics Corporation
    Inventor: Stewart A. Levin
  • Patent number: 8213260
    Abstract: A technique for performing a fast residual migration of seismic data through parsimonious image decomposition is presented. In one aspect, the technique includes a software-implemented method for processing a set of seismic data includes through parsimonious image decomposition. Other aspects of the technique include a program storage medium encoded with instructions that, when executed by a processor, perform such a method or a computing apparatus programmed to perform such a method.
    Type: Grant
    Filed: April 7, 2009
    Date of Patent: July 3, 2012
    Assignee: WesternGeco L.L.C.
    Inventor: David E. Nichols
  • Publication number: 20120106295
    Abstract: Embodiments of various technologies for a method for processing seismic data are disclosed. In one embodiment, a first portion of a record of pre-stack seismic data may be displayed in a three-dimensional XYZ (3-D XYZ) space. A selection may be received of a second portion of the record of the pre-stack seismic data within the first portion. One or more attributes may be determined that define the second portion. One or more regions may be identified within the record of the pre-stack seismic data having the attributes that define the second portion.
    Type: Application
    Filed: January 9, 2012
    Publication date: May 3, 2012
    Inventors: MATTHEW C. MILLER, RICHARD TACHON, ALAN G. TEAGUE, DEBRA M. DISHBERGER, YANN CUDENNEC, KAMRAN NADIM, STEPHEN DAVID HALL
  • Publication number: 20120092962
    Abstract: A technique includes processing first data indicative of a first image of a subsurface region of interest on a machine to generate second data indicative of a second image. The first image is derived from measurements of seismic waves, which propagate in a plurality of directions, and the second image is generated by partitioning the first image based on the directions. The technique includes processing the second data to determine a dip decomposition for each of the directions; and based on the dip decompositions and the directions, generating an angle domain common image gather.
    Type: Application
    Filed: April 6, 2011
    Publication date: April 19, 2012
    Inventors: David E. Nichols, Madhav Vyas, Everett C. Mobley
  • Publication number: 20120057431
    Abstract: A technique includes receiving first seismic data acquired by one or more receivers in response to energy produced by one or more seismic sources interacting with a subsurface feature. The first seismic data is indicative of measured reflection coefficients for image points for the subsurface feature, the measured reflection coefficients are associated with incidence angles, and a range of the incidence angles varies with respect to an image point position. The technique includes processing the first seismic data in a machine to generate second data indicative of a normal incidence reflection coefficient for at least one of the image points not associated with a normal angle of incidence.
    Type: Application
    Filed: September 7, 2011
    Publication date: March 8, 2012
    Applicant: WesternGeco L. L. C.
    Inventor: Walter Scott Leaney
  • Patent number: 8121791
    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.
    Type: Grant
    Filed: December 5, 2008
    Date of Patent: February 21, 2012
    Assignee: ExxonMobil Upstream Research Co.
    Inventors: Spyridon Lazaratos, Roy L. David
  • Publication number: 20120026832
    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.
    Type: Application
    Filed: July 27, 2010
    Publication date: February 2, 2012
    Applicant: SCHLUMBERGER TECHNOLOGY CORPORATION
    Inventors: Randolph E.F. PEPPER, Philippe Paul Jacques Marza, Agnes Dubois
  • Patent number: 8095320
    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.
    Type: Grant
    Filed: February 27, 2009
    Date of Patent: January 10, 2012
    Assignee: Saudi Arabian Oil Company
    Inventors: Roy Matthew Burnstad, Mahmoud Elabd Hedefa
  • Publication number: 20110317521
    Abstract: A method for predicting a plurality of surface multiples for a plurality of target traces in a record of seismic data acquired in a survey area. The method includes selecting a target trace and identifying two or more desired traces for multiple prediction based on the target trace. After identifying the desired traces, the method identifies one or more recorded traces for each desired trace. Each identified recorded trace is described as being substantially close to one of the desired traces. The method then includes correcting the identified recorded traces for one or more geometry-related effects associated with the survey area and convolving the corrected recorded traces to generate a plurality of convolutions. After convolving the corrected recorded traces, the method then stacks the convolutions.
    Type: Application
    Filed: June 29, 2010
    Publication date: December 29, 2011
    Inventors: William H. Dragoset, JR., Ian Moore
  • Patent number: 8045417
    Abstract: A system and method for locating subsurface diffractors. The method operates on two-dimensional (2-D) seismic data that includes one or more 2-D seismic lines. The 2-D seismic data may be preprocessed to enhance diffracted energy. For each hypothetical diffractor location in a set of hypothetical diffractor locations, the method involves analyzing at least a subset of the seismic traces of the one or more 2-D seismic lines, in order to compute a value indicating an extent to which those seismic traces contain diffraction arrivals consistent with the hypothetical diffractor location. The method may further involve generating, storing and displaying an image (or map) based on the computed values. The image may illustrate areas of high, intermediate and low diffraction, and may be used to assess the formation.
    Type: Grant
    Filed: May 26, 2009
    Date of Patent: October 25, 2011
    Assignee: Landmark Graphics Corporation
    Inventor: Stewart A. Levin
  • Publication number: 20110255370
    Abstract: Methods of and apparatus to image one or more subsurface formation features are disclosed. An example method includes generating acoustic waves with a transmitter and receiving the acoustic waves and acoustic data contained therein at one or more receivers. The example method also includes extracting one or more S-S, P-S or S-P reflected waveform data from the acoustic data, estimating a dip of the one or more subsurface formation features, migrating the one or more S-S, P-S or S-P reflected waveform data with the estimated dip and mapping the migrated one or more S-S, P-S or S-P reflected waveform data. In addition, the example method includes identifying one or more permeable subsurface formation features using the mapped migrated one or more S-S, P-S or S-P reflected waveform data.
    Type: Application
    Filed: April 15, 2011
    Publication date: October 20, 2011
    Applicant: SCHLUMBERGER TECHNOLOGY CORPORATION
    Inventors: NOBUYASU HIRABAYASHI, KENTARO TORII, HIROAKI YAMAMOTO, JAKOB HALDORSEN, ARNE VOSKAMP
  • Patent number: 7970546
    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.
    Type: Grant
    Filed: June 17, 2008
    Date of Patent: June 28, 2011
    Assignee: WesternGeco L.L.C.
    Inventor: Chengbin Peng