A volume of data is partitioned into a plurality of domains. A multilevel preconditioner is applied in the plurality of domains to provide iterative approximate solutions for the domains, which are coupled with boundary conditions. The approximate solutions for the domains are stitched together to provide a solution for a wave equation which can be used in full waveform inversion.
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
2.
PROCESSING WAVEFIELD DATA INCORPORATING LARGE TIMESTEPS AND UPSCALED MEDIUM PROPERTIES
Processing data representing a wavefield propagating through a medium by defining, based on one or more properties of a region of the medium and of the wavefield therein, a desired timestep and a desired spatial step for a discrete operator. Discrete seed operators having an initial timestep and an initial spatial step less than the desired timestep and the desired spatial step are then defined, and these seed operators are compounded to obtain an operator having a greater timestep and upscaled to obtain an operator having a greater spatial step. The compounding and upscaling are repeated until an operator having the desired timestep and the desired spatial step is obtained. The operator having the desired timestep and the desired spatial step may be applied to the data representing the wavefield propagating through a medium to propagate the data backwards in time to recreate the wavefield at earlier times.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
3.
DETERMINING AN OUTPUT REPRESENTING A TARGET STRUCTURE BASED ON ENCODED SOURCE AND RECEIVER DATA
A source wavefield is computed from encoded source data calculated by performing encoding of source wavelets with noise. A receiver wavefield is computed from encoded receiver data calculated by encoding of measured receiver data with the noise. An output representing a target structure is determined based on the source wavefield and the receiver wavefield.
A marine vibrator has a housing that comprises a displacement member, the displacement member having a first position and a second position, the housing and the displacement member together defining an internal volume. A linear electromagnetic motor interacts with the displacement member so as to move the displacement member between a first position and a second position and correspondingly strokes the displacement member to cover a volume. The linear electromagnetic motor comprises magnets and coils that when energized create an electromagnetic force there between, wherein the linear electromagnetic motor comprises a piston and a guide that substantially surrounds the piston. The piston has incorporated therein either the coils or the magnets, and the guide having incorporated therein the other of the coils or the magnets. The piston is in interaction with the displacement member.
Methods and systems for survey operations are provided. In some embodiments, crossline measurement data measured by at least one survey receiver is received. Based at least in part on a characteristic of the crossline measurement data, an option from among a plurality of candidate options is selected, where the selected option is for use in an action relating to survey of a target structure.
Acquired data that corresponds at least in part to a target structure is received. One or more subsets of a first type are formed from the acquired data. The one or more subsets of the first type are converted to one or more subsets of a second, different type.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
Methods and apparatuses for land seismic survey are provided. The methods and apparatuses utilize spatial derivatives of a seismic wavefield to interpolate,regularize or extrapolate seismic data. The methods and apparatuses may considerably reduce land seismic field efforts and/or compensate data gaps.
Performing seismic data processing using frequency diverse basis functions and converting a data processing problem into a one-norm or zero-norm optimization problem, which can be solved in frequency-space domain. The data processing problems can be data deghosting, data regularization or interpolation. The data being processed can be aliased or un-aliased, single sensor data or group-formed data,single component or multi-component data single source data or simultaneous sources, or some combinations.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
9.
METHODS AND DEVICES FOR ENHANCED SURVEY DATA COLLECTION
Methods and computing systems are disclosed for enhancing survey data collection. In one embodiment, a method is performed that includes deploying an array of marine seismic streamers, wherein respective streamers in the array include a plurality of seismic receivers; towing the array of marine seismic streamers; actively steering the array of marine seismic streamers; and while actively steering the array of marine seismic streamers, maintaining a tow-depth profile for the array such that the plurality of seismic receivers are configured to acquire seismic data having a receiver ghost response frequency that varies linearly.
An objective function is based on covariance of differences in predicted data over multiple sets of candidate model parameterizations that characterize a target structure. A computation is performed with respect to the objective function to produce an output. An action selected from the following can be performed based on the output of the computation: selecting at least one design parameter relating to performing a survey acquisition that is one of an active source survey acquisition and a non-seismic passive acquisition, and selecting a data processing strategy.
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/26 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device
A method for removing seismic noise from an input seismic trace. The method may receive the input seismic trace. The method may receive one or more noise references for the input seismic trace. The method may receive one or more filters corresponding to the noise references. The method may apply a nonlinear function to the input seismic trace and to the one or more noise references to produce respective output signals for the input seismic trace and for the one or more noise references. The nonlinear function may be capable of determining higher-order statistics. The method may update the filters based on increasing one or more information attributes of the output signals to a predetermined threshold. The method may then filter noise corresponding to the noise references.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
A seismic vibrator includes a baseplate having a surface configured to couple to a ground surface. A driver is coupled to the baseplate and is configured to move the baseplate in a vibratory manner. A decoupling system is coupled to a part of the baseplate other than the ground-contacting surface. The decoupling system includes a first layer having a Young's modulus greater than that of a second layer coupled to the first layer. The second layer is coupled to the baseplate. The Young's moduli, thicknesses and masses of the first and second layer are selected to provide the decoupling system with a resonant frequency of at most, a spatial aliasing frequency of seismic sensors deployed on the ground surface or a lowest seismic frequency of interest.
An embodiment of the invention includes combining pseudorandom sweeps with an independent, or nearly independent, survey acquisition technique. Targeted design of pseudorandom sweeps can direct the majority of cross-correlation noise to lie outside key time-lags of the record (i.e., windows of interest). Embodiments of the invention are described herein.
An embodiment of the invention includes simultaneous drive signals whose respective phase angle offset(s) varies over a portion or duration of the simultaneous sweeps. Other embodiments are discussed herein.
A seismic survey method including determining an expected time when an actuation step will be performed by a seismic source device, transmitting a signal from the seismic source device to a source control system thereby alerting the source control system of the expected time when the actuation step will be performed by the seismic source device; and in response to the signal from the seismic source device, providing a communication from the source control system to the seismic source device.
A computer-implemented method of determining a search expression describing a feature of interest in a set of data points distributed throughout a geological object is provided. Each data point contains a value for a geological attribute at that point. The search expression has a plurality of entries. The method including the steps of: (i) displaying the geological object using display codings corresponding to value subranges for the geological attribute such that all data points which have values for the geological attribute falling within a given value subrange are displayed with the same coding; (ii) selecting a plurality of data points of the feature of interest; and (iii) allocating value characters to entries of the search expression, the value characters corresponding to the value subranges for the geological attribute of the selected data points.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
17.
ATTENUATING NOISE ACQUIRED IN AN ENERGY MEASUREMENT
A technique includes receiving data corresponding to at least one measurement of energy produced by a shot of an energy source; and transforming the received data to a domain that is sensitive to event direction. The technique includes comparing the measurement(s) with a reference based at least in part on the transformation; and based at least in part on the comparison, attenuating noise from the measurement(s).
A technique includes determining at least one impulse response of a modeling and migration of at least one point scatterer in a target structure and based at least in part on the impulse response(s) and a reflection amplitude image, determining a model for at least part of the target structure.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
A technique includes receiving sensor acquired data, which includes pressure data representative of at least one pressure measurement of a wavefield and particle motion data representative of at least one particle motion measurement of the wavefield. The technique includes filtering the pressure data and the particle motion data with a plurality of directional filters to provide a plurality of filtered datasets. The filtered datasets are associated with different directional ranges. The technique includes estimating an angle of incidence for at least one of the directional ranges based at least in part on at least one of the filtered datasets; and processing the acquired data to determine at least one of an upgoing component of the wavefield and a downgoing component of the wavefield based at least in part on the at least one estimated angle of incidence.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
A method to perform a marine seismic survey includes obtaining marine seismic data corresponding to a subterranean formation under a water surface. The marine seismic data is generated from an underwater seismic sensor that is subject to an interference effect. The method further includes generating, by a computer processor and using a deconvolution operation, corrected marine seismic data based at least in part on the marine seismic data to compensate for the interference effect, and generating, by the computer processor, a marine seismic survey result based at least in part on the corrected marine seismic data.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
Methods and apparatuses for an inversion process in an imaging process, in which 3-D surface models are used to explicitly represent complex boundaries, in which the 3-D surface models and the gridded models are linked by projection and model gridding, and in which the 3-D surface models and the gridded models are updated during inversion.
Methods and apparatuses for acquiring marine seismic data to generate images or determine properties of an interior section of the Earth using simultaneous marine vibrator sweeps and methods for processing the acquired seismic data. Phase of sweeps produced by the marine vibrator(s) are controlled to provide for removal of crosstalk. The phases between marine vibrator sweeps may be random or controlled to have a predetermined/desired phase difference. The predetermined phases may be determined to minimize the crosstalk between sweeps based on known seismic velocity of the survey area.
Methods and apparatuses for acquiring marine seismic data to generate images or determine properties of an interior section of the Earth using simultaneous sources. The time required to acquire a seismic survey is decreased by increasing the speed of the source towing vessel (or decreasing the data sampling density, or increased sampling interval) using multiple simultaneous sources. After separation with simultaneous source technique and combination of separated datasets, seismic data with designed data sampling density or better are acquired.
A method to parameterize the geometry of a geological, subsurface feature such as a salt body is provided. Data corresponding to a subsurface, geological formation is acquired. The acquired formation data corresponds to a subsurface body having a certain geometry and a subsurface region. At least part of the subsurface body geometry is directly inverted into an inversion domain. The direct inversion includes partitioning the inversion domain into a first partitioned region, corresponding at least in part to the subsurface body, and a second partitioned region. The inversion further uses a level set representation to parameterize the subsurface body geometry. A computing system that includes a processor, a memory, and one or more programs stored in the memory is also provided. The programs comprise instructions that, when executed by the processor, are configured to perform the provided method.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
Generating an image of an interior of the Earth from a seismic survey using multiple sources. The multiple sources may be fired simultaneously and the data received by seismic sensors in the seismic survey may be decomposed so that seismic data generated by each of the multiple sources may be determined. Decomposing of the received data may be performed using frequency diverse basis functions and converting the data separation problem into an optimization problem, which can be a one-norm or zero-norm optimization problem in frequency-space domain. The decomposed data may be used to generate the image of the Earth's interior.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
26.
METHODS AND COMPUTING SYSTEMS FOR SURVEY DATA ENHANCEMENT
Methods and systems are disclosed to enhance surveying techniques. In one embodiment, a virtual response is estimated that corresponds to energy propagated within a subsurface region between a virtual source and a virtual source estimation receiver, wherein the subsurface region corresponds to a survey zone including: a plurality of receivers deployed within the survey zone, a first subzone having at least one actual source, a second subzone within the first subzone; the virtual source is a first receiver disposed in the second subzone; and the virtual source estimation receiver is a second receiver.
Seismic surveying techniques are described in which seismic receivers in a seismic array are used as seismic sources. These receiver-sources may be used to determine the near-surface structures of the Earth, geometric properties of the survey array, receiver locations and operations of the survey array. The receiver-sources may be driven by drive sequences to produce amplified receiver-source signals, plane waves, surface waves converging towards a point inside the seismic array, surface waves sweeping through the seismic array and/or the like. The receiver-sources may comprise geophones, hydrophones, accelerometers and/or the like. A driver may be used to drive the receiver- sources and the driver may be controlled by a processor. By encoding drive sequences, seismic data generated by the receiver-sources may be separated from seismic data generated by another seismic source in the seismic array. Similarly, seismic data can be separated by controlling the frequency of seismic signals produced by the receiver-sources.
Methods and apparatuses for processing seismic data to generate images or determine properties of an interior section of the Earth. The seismic data is processed to filter coherent noise such as ground roll noise from seismic survey data. The noise is attenuated using 3D and/or 2D fan filters, which may have combined low-pass and band-pass filters derived from signal decomposition. The filters are designed with selected operator length, velocity bands of signals and noises and frequency range for a primary trace and adjacent traces within the operator length. The data is decomposed with the filters into signals and noises, and the noises are then filtered from the decomposed data. The process may be repeated for various frequencies and traces within the seismic data. The methods may be used for surveys that have either regular or irregular seismic receiver or seismic source positions.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
A method for removing noise from a three-dimensional representation of seismic data. The method includes receiving seismic data acquired in a seismic survey. The method may organize the acquired seismic data into a three-dimensional representation of the acquired seismic data. The method may then remove a noise from the three-dimensional representation of the acquired seismic data based on at least one criterion.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
30.
METHODS AND DEVICES FOR TRANSFORMATION OF COLLECTED DATA FOR IMPROVED VISUALIZATION CAPABILITY
Computing systems and methods for improving imaging of collected data are disclosed. In one embodiment, a first wavefield is propagated to obtain a first wavefield history; the first wavefield is again propagated to obtain a second wavefield history, wherein the propagation includes integration of one or more Q-effects; a first attenuated traveltime history is estimated based at least in part on the first and second wavefield histories; a first Q-model filter is calculated based at least in part on the first estimated attenuated traveltime; and a first adjusted wavefield is generated based at least in part on application of the first Q-model filter to the first wavefield. In some embodiments, an image is generated based at least on a first adjusted wavefield and a second wavefield.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
Methods and systems for survey designs are disclosed. In one embodiment, a method of towing an array of marine streamers is disclosed, wherein: the array includes a plurality of receivers, the array includes a plurality of steering devices, and the array is towed along a first portion of a coil sail path; steering the array of marine streamers along two or more depths; and steering the array of marine streamers to a slant angle while maintaining the array of marine streamers at their respective two or more depths.
Seismic data relating to a subterranean structure is received from at least one translational survey sensor, and gradient sensor data is received from at least one gradient sensor. A P wavefield and an S wavefield in the seismic data are separated, based on combining the seismic data and the gradient sensor data.
A method of acoustic positioning determination includes detecting a temperature gradient profile across a depth of water, determining a level of a thermal boundary between an upper temperature level and a lower temperature level, and determining a distance from the thermal boundary to position the acoustic positioning device and positioning the acoustic positioning device at that location.
Methods and computing systems for multiple-domain inversion are disclosed to enhance subsurface region evaluation. In one embodiment, three or more datasets corresponding to a subterranean region are received, wherein at least one of the datasets is a magnetic dataset; and the three or more datasets are jointly inverted to generate at least a velocity model that corresponds to at least a first part of the subterranean region, and a susceptibility model that corresponds to at least the first part of the subterranean region, wherein the velocity model and the susceptibility model are correlated.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
35.
DETERMINING ONE OR MORE TARGET POSITIONS IN AN ACQUISITION DOMAIN FOR PROCESSING SURVEY DATA
In response to at least one input criterion, one or more target positions in an acquisition domain are determined for processing of survey data, where the survey data is acquired by survey equipment in the acquisition domain having a first set of dimensions, and where the processing of the survey data is to be performed in a processing domain having a second set of dimensions different from the first set of dimensions.
A method for processing seismic data. The method includes receiving the seismic data acquired by at least two receivers that are disposed at different depths. The method may then time-align the seismic data, collect a portion of the time-aligned seismic data into a gather and sum the collected time-aligned seismic data in the gather. After summing the collected time-aligned seismic data in the gather, the method may widen a spectrum of the summed seismic data and generate an image of subsurface formations in the earth based on the widened spectrum.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
37.
SEISMIC SURVEY DESIGNS FOR ATTENUATING SEA-SURFACE GHOST WAVE EFFECTS IN SEISMIC DATA
A method for acquiring seismic data. The method may include towing an array of marine seismic streamers coupled to a vessel. The array includes a plurality of receivers and a plurality of steering devices. The method may further include steering the array of marine seismic streamers to be towed along two or more depths, and steering the array of marine seismic streamers to a slant from an inline direction while maintaining the array of marine seismic streamers at their respective two or more depths.
Measurement data acquired by at least one sensor in a cable structure towed through a body of water is received. A torsional vibration noise component in the measurement data is estimated. The torsional vibration noise component is used to estimate a rotation angle of the at least one survey sensor with respect to a reference coordinate system of the cable structure.
An anti-biofouling material for use on marine equipment is described, the anti-biofouling material comprising a polymer system comprising a hydrophobically-modified base polymer, the hydrophobically-modified base polymer comprising a base polymer having a backbone and a hydrophobically derivatized chain extender coupled to said backbone of said base polymer, wherein the the hydrophobically derivatized chain extender comprises a hydrophobic moiety. The anti-fouling casing comprises a hydrophobic surface the serves to prevent biofouling of the surface.
A technique is designed for conducting a seismic survey. The technique utilizes a plurality of vibrator arrays employed to conduct a seismic survey utilizing low frequency and high frequency vibrators in each vibrator array. The plurality of vibrator arrays continuously sweeps low frequency signals via low frequency vibrators. While sweeping low frequency signals, high-frequency vibrators emit high-frequency signals in an alternating pattern between vibrator arrays to enhance the seismic survey.
PRAD RESEARCH AND DEVELOPMENT LIMITED (United Kingdom)
SCHLUMBERGER TECHNOLOGY CORPORATION (USA)
GECO TECHNOLOGY B.V. (Netherlands)
Inventor
Hopperstad, Jon-Fredrik
Laws, Robert
Tulett, John, Richard
Abstract
A technique provides a source design and method for increasing low frequency output of a marine source array. The approach comprises providing a plurality of airguns. At least some of the airguns are activated to generate an effective bubble energy. The effective bubble energy may be optimized through use, preparation and/or arrangement of the airguns.
G01V 3/15 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for use during transport, e.g. by a person, vehicle or boat
Methods for indirect data acquisition via exact inverse receiver extrapolation. The desired data are obtained from extrapolation of directly measured data containing a wavefield quantity (e.g. pressure) and a component of its gradient. The methods use exact representations of scattering reciprocity. Methods of evaluating/validating the extrapolated data are also disclosed. These methods can be used in any industries involving imaging, such as geophysical/seismic exploration, bio-medical imaging, non-destructive remote sensing, acoustic space architecture, design and engineering.
Methods for wavefield extrapolation using measurements of a wavefield quantity and a component of the gradient of the wavefield quantity are disclosed. The methods use "exact" representations of scattering reciprocity. The methods can yield "exact", nonlinear, "true-amplitude" receiver wavefields that are beyond the receiver measurement boundary. Methods of evaluating/validating the extrapolated data are also disclosed. Some methods may also evaluate the accuracy of models for the areas where data are extrapolated or measured. These methods can be used in any industries involving imaging, such as geophysical/seismic exploration, bio-medical imaging, non-destructive remote sensing, acoustic space architecture, design and engineering.
Prior information describing a distribution of values of a parameter relating to physical characteristic of a target structure is received. Acquired survey data of the target structure is received. Using a probabilistic technique, the prior information and the survey data is assimilated to produce an estimated property of the target structure.
Methods and computing systems for hydrocarbon exploration are disclosed. In one embodiment, an integrated petroleum systems model is generated for an area of interest, wherein the integrated petroleum systems model is based on: a geological outline, a set of satellite remote sensing data, and a set of airborne remote sensing data.
Translational data acquired by at least one translational survey sensor is received, and rotation data is received. A representation of wavefield velocity based on the translational data and the rotation data is determined.
A marine seismic exploration device includes a vessel; a sensor device on the vessel that senses movement of the vessel; a connection device that comprises an electric motor; a controller that communicates with the sensor device and the motor; and a seismic sensor connected with the connection device. The connection device has at least a first position where the connection device extends a first length and a second position where the connection device extends a second length, wherein the second length is longer than the first length. The controller is programmed to compensate for the movement of the vessel detected by the sensor by moving the connection device between positions to control the length that the connection device extends.
Methods of acquiring and processing seismic data using derivative sensors, such as strain sensors,that facilitate ground roll noise attenuation with seismic interferometry are disclosed. The methods use both seismic data and their spatial derivatives in computing ground-roll noises which are removed from processed seismic data.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
Measured seismic data is received from a seismic sensor. Rotation data is also received, where the rotation data represents rotation with respect to at least one particular axis. The rotation data is combined, using adaptive filtering, with the measured seismic data to attenuate at least a portion of a noise component from the measured seismic data.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
50.
WAVEFORM INVERSION USING A RESPONSE OF FORWARD MODELING
Forward modeling is performed to compute a response of a target structure, the forward modeling accounting for distortion of a reflected signal from a reflector in the target structure. Waveform inversion is performed using the response of the forward modeling.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
51.
SELECTING A SURVEY SETTING FOR CHARACTERIZING A TARGET STRUCTURE
Complex-valued sensitivity data structures corresponding to respective candidate survey settings are provided, where the sensitivity data structures relate measurement data associated with a target structure to at least one parameter of a model of the target structure. Based on the sensitivity data structures, a subset of the candidate survey settings is selected according to a criterion for enhancing resolution in characterizing the target structure.
G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
G01V 1/16 - Receiving elements for seismic signalsArrangements or adaptations of receiving elements
52.
FREQUENCY-DEPENDENT RAY TRACING THROUGH AN INTERFACE
Computing systems and methods for improving processing of collected data are disclosed. In one embodiment, while ray-tracing through a sub-surface region, a frequency-dependent outgoing ray direction is computed from a point on an interface disposed in the sub-surface region when the ray tracing is at the interface.
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
53.
MARINE VIBRATOR SWEEPS WITH REDUCED SMEARING AND/OR INCREASED DISTORTION TOLERANCE
A marine seismic survey using one or more moving marine seismic vibrators, where the vibrator sweeping function is based on smearing error criteria and is a downward-sweeping nonlinear sweep function. The acquired seismic data can either be used as is without desmearing or desmeared easily.
Marine seismic survey using one or more marine seismic vibrators, where the vibrator sweep function is based on a quality requirement, which may be a final image quality requirement or an environmental requirement. The sweep function may be nonlinear and the energy spectrum may not match the energy spectrum of an airgun.
Seismic data processing methods and computing systems are presented. In one embodiment, a method is disclosed that includes simulating a set of simulated seismic data from a set of acquired seismic data; separating the simulated seismic data into a plurality of data sets, wherein one set of data is matched in the acquired seismic data and one set of data is unmatched in the acquired seismic data; conforming the simulated seismic data and the acquired seismic data to one another using separated, simulated seismic data unmatched by a counterpart in the acquired seismic data from the acquired seismic data; and performing an inversion between the acquired seismic data and the separated, simulated seismic data after they are conformed to one another.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
56.
ELECTROMAGNETIC SOURCE TO PRODUCE MULTIPLE ELECTROMAGNETIC COMPONENTS
An electromagnetic (EM) source assembly for performing marine subterranean surveying includes electrodes in an arrangement configured for towing through a body of water. A controller is configured to selectively activate different sets of the plurality of electrodes, where a first of the sets produces an EM field in a first direction, and where a second of the sets produces an EM field in a second, different direction.
G01V 3/165 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for use during transport, e.g. by a person, vehicle or boat operating with magnetic or electric fields produced or modified by the object or by the detecting device
G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
57.
DEVICES AND METHODS FOR POSITIONING TOWS IN MARINE SEISMIC SYSTEMS
A method and system for deploying seismic tows, such as seismic streamers, from a common carrier rope for conducting marine seismic surveys. The deployment system generally comprises a carrier rope having at least one deflector urging the carrier rope laterally relative to the towing vessel and seismic tows that are independently moveable along the deployed carrier rope to desired locations from which to be deployed. The carrier rope may be deployed from the tow vessel into the water prior to deploying the seismic streamer(s) into the water.
A seismic vibrator receives a pilot signal having a predetermined waveform. The pilot signal causes vibrational actuation of at least one moveable element of the seismic vibrator. A continuous seismic signal having content in a first frequency bandwidth of multiple frequencies is generated by the seismic vibrator.
A technique includes performing reverse time imaging to determine an image in a region of interest. The reverse time imaging includes modeling a pressure wavefield and a gradient wavefield in the region of interest based at least in part on particle motion data and pressure data acquired by sensors in response to energy being produced by at least one source.
A technique includes decomposing a signal that is derived from a seismic acquisition into a plurality of signals such that each signal is associated with a different frequency band. For each signal of the plurality of signals, the technique includes performing the following: decomposing the signal into subbands in successive stages, where the subbands are associated with at least different frequency ranges of the signal; selectively applying adaptive noise attenuation in between the successive stages such that the stages decompose noise-attenuated subbands; and reconstructing the signal from the subbands resulting from the decomposition. The technique includes combining the reconstructed signals.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
61.
METHOD AND COMPUTING SYSTEMS FOR IMPROVED IMAGING OF ACQUIRED DATA
Methods and computing systems are disclosed to enhance imaging of acquired data. In one embodiment, a method is performed that includes receiving acquired data that corresponds to the medium; computing a first wavefield by injecting a noise; and computing the cumulative illumination by auto-correlating the first wavefield.
A method for processing seismic data. The method may include receiving seismic data due to a plurality of seismic sources and applying a first operator to the seismic data in an ith domain to generate a first estimate of seismic data due to an ith seismic source. The ith domain may correspond to the ith seismic source of the plurality of seismic sources. The method may then include applying a second operator to the first estimate of seismic data due to the ith seismic source in one or more domains other than the Ith domain to generate residual seismic data due to one or more seismic sources other than the Ith seismic source. After applying the a second operator to the first estimate of seismic data due to the ith seismic source, the method may determine a second estimate of seismic data due to the ith seismic source based on the first estimate and the residual seismic data due to the seismic sources other than the Ith seismic source. The method may then repeat some of the steps described above (i.e., applying a first operator to the seismic data, applying a second operator to the first estimate of seismic data and determining a second estimate of seismic data due to the Ith seismic source for each seismic source). The method may then process the second estimate of seismic data due to each seismic source to determine the presence of hydrocarbon deposits in a subterranean area of the earth.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
63.
ELECTROMAGNETIC MEASUREMENTS USING A SENSOR CABLE HAVING IMPROVED CHARACTERISTICS
To survey a subterranean structure, for acquiring an electromagnetic (EM) measurement signal across EM receivers having a target axial spacing, a group of more than two EM receivers in an interval defined by the target axial spacing along a sensor cable is provided. The spacing between successive ones of at least some EM receivers in the group is less than the target axial spacing. EM measurements are acquired using the EM receivers in the group.
G01V 3/165 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for use during transport, e.g. by a person, vehicle or boat operating with magnetic or electric fields produced or modified by the object or by the detecting device
G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
64.
DETERMINING STREAMER DEPTH AND SEA SURFACE PROFILE
A technique includes receiving data indicative of acoustic measurements acquired by receivers disposed on a seismic receiver spread including at least one streamer. The technique includes processing the data in a machine to determine a depth and/or shaped of the spread.
To perform surveying of a subterranean structure, an electromagnetic (EM) source array has a plurality of electrodes. Different subsets of the electrodes are dynamically activated to provide corresponding EM radiation patterns to survey the subterranean structure.
G01V 3/165 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for use during transport, e.g. by a person, vehicle or boat operating with magnetic or electric fields produced or modified by the object or by the detecting device
G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
A method for processing seismic data. The method may include (1) receiving seismic data acquired by an ith seismic sensor of a plurality of seismic sensors and (2) determining an ith value to represent an ith power spectral density curve that corresponds to the seismic data. The method may then repeat steps (1)-(2) for each seismic sensor. The method may then include generating an expected value curve based on the ith value for each power spectral density curve. The method may then compare each ith value to the expected value curve and identify invalid seismic sensors based on the comparison. After identifying the invalid seismic sensors, the method may process the seismic data without seismic data acquired by the invalid seismic sensors to determine one or more locations of hydrocarbon deposits in subterranean geological formations.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
A method for processing seismic data. The method may include (1) receiving seismic data acquired by an ith seismic sensor of a plurality of seismic sensors and (2) determining an ith value to represent an ith power spectral density curve that corresponds to the seismic data. The method may then repeat steps (1)-(2) for each seismic sensor. The method may then include generating an expected value curve based on the ith value for each power spectral density curve. The method may then compare each ith value to the expected value curve and identify invalid seismic sensors based on the comparison. After identifying the invalid seismic sensors, the method may process the seismic data without seismic data acquired by the invalid seismic sensors to determine one or more locations of hydrocarbon deposits in subterranean geological formations.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
68.
ACTIVE DETECTION OF MARINE MAMMALS DURING SEISMIC SURVEYING
An embodiment according to one or more aspects of the present disclosure for conducting a marine survey includes towing a survey spread comprising a plurality of receivers and an energy source along a selected course; emitting a signal from an energy source; receiving backscattered acoustic signals at the receivers; and actively detecting a cetacean from the received data.
Passive seismic data is collected from measurements of seismic sensors in respective sensor assemblies, where the passive seismic data is based on measurements collected during periods when no active seismic source was activated. Attenuation of surface noise in the passive seismic data is performed using data from divergence sensors in at least some of the sensor assemblies. The passive seismic data with surface noise attenuated is output to allow for performing an operation related to a subterranean structure using the passive seismic data with the surface noise attenuated.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
70.
COMPUTING A CALIBRATION TERM BASED ON COMBINING DIVERGENCE DATA AND SEISMIC DATA
Divergence data is received from a divergence sensor and seismic data is received from seismic sensors, where the divergence sensor and seismic sensors are part of a sensor assembly. A calibration term is computed based on combining the divergence data and the seismic data, where the calibration term includes a first parameter that is related to a characteristic of the sensor assembly, and a second parameter that is related to a characteristic of a near-surface subterranean medium.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
A method for processing seismic data. The method includes receiving the seismic data acquired at one or more receivers due to one or more marine vibroseis sources that emit one or more vibroseis sweeps. The method then applies a receiver motion correction algorithm to the received seismic data to generate receiver motion corrected seismic data. After generating the receiver motion corrected seismic data, the method transforms the receiver motion corrected seismic data into a temporal Fourier domain to generate seismic data as a function of frequency. The method then reconstructs the transformed seismic data as a function of frequency to correct for one or more motions of the one or more marine vibroseis sources. After reconstructing the transformed seismic data, the method transforms the reconstructed seismic data to the time domain. The method then generates a seismic image of a subsurface of the Earth based on the transformed reconstructed seismic data.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
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.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
73.
MATCHING PURSUIT-BASED APPARATUS AND TECHNIQUE TO CONSTRUCT A SEISMIC SIGNAL USING A PREDICTED ENERGY DISTRIBUTION
A technique includes processing seismic data indicative of samples of at least one measured seismic signal in a processor-based machine to, in an iterative process, determine basis functions, which represent a constructed seismic signal. The technique includes in each iteration of the iterative process, selecting another basis function of the plurality of basis functions. The selecting includes based at least in part on the samples and a current version of the constructed seismic signal, determining a cost function; and interpreting the cost function based at least in part on a predicted energy distribution of the constructed seismic signal to select the basis function.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
74.
EFFICIENT SEISMIC SOURCE OPERATION IN CONNECTION WITH A SEISMIC SURVEY
An embodiment includes determining whether first and second seismic sources are ready to perform seismic sweeps. When either of the first and the second seismic sources are determined to be unready to perform seismic sweeps, the method includes (a) determining a predicted time delay that will transpire before the first and the second seismic sources will both be ready to perform seismic sweeps; (b) determining a predicted distance that will exist between the first and second seismic sources once the first and second sources are both ready to perform seismic sweeps; (c) determining the predicted time delay meets a time threshold and the predicted distance meets the distance threshold, and then (d) initiating simultaneous seismic sweeping with the first and second seismic sources after the first and the second seismic sources are both ready to perform seismic sweeps.
A marine vibrator with improved seal is described. The marine vibrator includes a housing and piston within the housing for generating vibratory signals. The improved seal is comprised of a two-stage seal having a first seal disposed adjacent the water interface and a second seal disposed away from the water interface, thus improving the reliability of the marine vibrator.
A technique includes receiving particle motion data acquired by particle motion sensors while in tow. The particle motion data are indicative of a seismic signal and a torque noise, and the particle motion sensors are oriented to modulate a wavenumber of a first component of the torque noise away from a signal cone that is associated with the seismic signal. The technique includes estimating the first component of the torque noise and based at least in part on the estimated first component, estimating a second component of the torque noise inside the signal cone. The technique includes suppressing the second component of the torque noise based at least in part on the estimated second component.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
77.
MONITORING THE QUALITY OF PARTICLE MOTION DATA DURING A SEISMIC ACQUISITION
A technique includes acquiring particle motion data from a plurality of particle motion sensors while in tow during a seismic survey. During the seismic survey, the particle motion data are processed without deghosting the particle motion data to determine whether at least some portion of the particle motion data is inadequate for an application that relies on the particle motion data.
A method for processing seismic data. The method includes receiving the seismic data acquired at two or more sensors on a towed marine survey and regularizing the received seismic data into a spatial domain. After regularizing the seismic data, the method includes classifying the regularized seismic data below and equal to a predetermined frequency as low-frequency seismic data. The method then calculates a set of low-frequency Green's functions using interferometry on the low-frequency seismic data described above. The method then processes high-frequency seismic data of the seismic data to create a set of high-frequency Green's functions at one or more source locations of the towed marine survey. The method then merges the set of low-frequency Green's functions and the set of high-frequency Green's functions to create a set of broad-band Green's functions at the source locations.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
An apparatus includes a streamer cable section and a unit. The streamer cable section includes an associated group of seismic sensors. The unit connects to an end of the streamer cable section and includes a steering device, a controller, a network repeater and a router. The steering device is controllable to position the streamer section; the controller gathers seismic data provided by the associated group of seismic sensors and introduces the seismic data to a telemetry network of a streamer; the network repeater repeats a signal communicated along the telemetry network; and the router is disposed between the controller and the telemetry network.
According to one or more aspects of the invention, a marine seismic survey method comprises towing at least two streamers below a sea surface forming a survey spread, each streamer comprising a survey sensor and a profiler; and at each profiler, emitting an acoustic signal; recording an echo of the emitted signal at the profiler; and determining a parameter from the recorded echo, the parameter comprising at least one selected from the group of a distance between the profiler and the sea surface, a water current vector and a sea surface slope.
A technique enables measuring of the actual firing sequence times in a seismic survey application. The actual firing sequence times are then employed in simultaneous source resolution methods. For example, simultaneous seismic sources may be deployed in a survey region. The seismic sources are then fired, and the actual firing times are determined and recorded for use in optimizing the seismic survey.
A seismic cable for use in land applications is described. The cable includes seismic sensors for measuring seismic signals reflected from subterranean or subsea formations. The cable may be deployed in trenches dug in the survey region to provide adequate sensor coupling to ground. Sensor units may be inline with the cable and may further be disposed in slim casings, thus facilitating handling and deployment.
Systems and methods for carrying out seismic surveys and/or conducting permanent reservoir monitoring with autonomous or remote-controlled water vehicles, including surface and submersible vehicles, are described. Additional methods carried out by autonomous or remote-controlled water vehicles and associated with seismic surveys are further described.
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.
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
Systems and methods for optimizing low frequency output of marine sources are described. The marine source arrangements and associated methods disclosed herein seek to fully frequency lock bubbles emitted by airguns in close proximity to one another. In this manner, larger effective bubble volumes can be achieved, thus increasing low frequency output.
A technique includes using an accelerometer to provide an output signal indicative of an acceleration experienced by a movable mass of a sensor of the accelerometer. The technique includes testing the accelerometer, and the testing includes using a closed loop including the sensor to provide the output signal of the accelerometer; injecting a test signal into the loop between an output terminal of the sensor and an output terminal of the accelerometer; and indicating a performance of the accelerometer based on a response of the accelerometer to the injection of the test signal.
A method for removing internal multiples from collected data, such as seismic data. The method includes predicting internal multiples for each horizon in a plurality of horizons that created the internal multiples. The internal multiples may be predicted from the seismic data in one pass. After predicting the internal multiples, the method includes creating a separate model of internal multiples for each horizon based on the predicted internal multiples for each horizon. The method then iteratively subtracts each separate model of internal multiples for each horizon from the seismic data.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
A sensor assembly has first sensors spaced apart along a first direction, and second sensors oriented in a second direction generally orthogonal to the first direction. Differencing of outputs of the first sensors is performed, and differencing of outputs of the second sensors is performed. A signal output is produced by combining the differenced outputs of the first sensors and the differenced outputs of the second sensors, where the signal output represents a seismic response of a subterranean structure.
A distributed optical acoustic sensor is provided along a structure in a body of water. The distributed optical acoustic sensor is used to detect acoustic waves generated by at least one acoustic source for positioning of at least one object in relation to the structure.
A technique includes during a seismic acquisition, selectively forming groups of at least one seismic source from a plurality of seismic sources as the seismic sources become available based at least in part on a minimum source spacing distance. The technique also includes selectively activating the groups. Each group responds to being activated by substantially simultaneously initiating a sweep for the seismic source(s) of the group. The technique further includes regulating a timing of the group activations based at least in part on a slip time and a minimum group spacing distance.
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.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
Methods to attenuating strong marine seismic noises using singular value decomposition, determining noisiest traces and estimating noise components only from these traces, iteratively estimating the noise and protecting signal behind the noise. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
93.
Methods and Devices for Transformation of Collected Data for Improved Visualization Capability
Rock physics guided migration is disclosed to enhance subsurface three-dimensional geologic formation evaluation. In one embodiment, a geologic interpretation is generated based on a seismic data volume. Sets of compaction and acoustic formation factor curves are generated, and these are combined into a set of velocity-relationship curves. A pore pressure is derived and used to establish a pore pressure state. A rock physics template is then generated utilizing the derived information. This rock physics template can be used to refine geologic formation evaluation with any suitable form of migration technique.
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
94.
REGULATING COHERENT BOUNDARY REFLECTIONS DURING GENERATION OF A MODELED WAVEFIELD
A technique includes receiving data indicative of a wavefield in a processor-based system and processing the data on the processor-based system to generate a modeled wavefield. The processing includes varying boundary conditions of the modeled wavefield with respect to time to regulate coherent boundary reflections in the modeled wavefield.
A technique includes receiving requests from mobile seismic sources and organizing the requests in a queue. The seismic sources are associated with respective paths of a survey plan, and each request indicates that one of the seismic sources is ready for an action to be performed by the seismic source. The technique includes regulating an ordering associated with the requests based on survey parameters and responding to the requests according to the ordering.
An embodiment of the invention may extend the range of wireless communications in a seismic acquisition survey. The embodiment may leverage the infrastructure of a hard-wired communications backbone by appending wireless cells to the hard-wired communications. This may allow, for example, a recording truck to control remotely located seismic sources via wireless communications in the spread. Another embodiment includes a communication system for servicing field equipment. The embodiment provides for a fully or semi automated process for communicating equipment failures between survey personnel (e.g., recording truck operators and line observers). The embodiment establishes an end-to-end channel between, for example, the recording truck and field crew members. Other embodiments are disclosed herein.
A technique includes receiving seismic data acquired by seismic sensors; and processing the seismic data on a machine to deghost the data. The processing includes deghosting the seismic data using a first deghosting technique that relies on a ghost model; deghosting the seismic data using a second deghosting technique that is independent from any modeling of the ghost; and selectively combining the results of the deghosting using the first and second deghosting techniques.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
98.
DETERMINING A QUANTITY OF A GIVEN MATERIAL IN A SUBTERRANEAN STRUCTURE
A profile is produced based on measured survey data, where the profile contains indications corresponding to refraction events at different depths in a subterranean structure. Based on the profile and a critical angle model that correlates different concentrations of a given material to respective critical angles, a quantity of the given material in a subterranean structure at a particular depth is determined.
G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G06F 19/00 - Digital computing or data processing equipment or methods, specially adapted for specific applications (specially adapted for specific functions G06F 17/00;data processing systems or methods specially adapted for administrative, commercial, financial, managerial, supervisory or forecasting purposes G06Q;healthcare informatics G16H)
To perform seismic surveying, a plurality of sensor assemblies are provided, where each of multiple ones of the plurality of sensor assemblies has a seismic sensor and a divergence sensor, and where the divergence sensor is used to measure noise. In addition, the plurality of sensor assemblies are arranged in a layout designed to acquire seismic signals in a target sampling pattern, where the layout is independent of provision of sensor assemblies for noise acquisition.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
100.
PROVIDING A TRANSFORM FUNCTION TO PRODUCE A MECHANICAL PROPERTY OF A SUBTERRANEAN STRUCTURE
A transform function is useable to map a characteristic (e.g., acoustic impedance, shear impedance, density, and/or other characteristic) to a mechanical property (e.g., Young's modulus or other mechanical property). Values of the characteristic can be derived based on surface survey data, and such values can be mapped to respective values of the mechanical property using the transform function.
patents