# Specific display system (e.g., mapping, profiling)

## Subclass of:

## 702 - Data processing: measuring, calibrating, or testing

## 702001000 - MEASUREMENT SYSTEM IN A SPECIFIC ENVIRONMENT

## 702002000 - Earth science

## 702014000 - Seismology

### Patent class list (only not empty are listed)

#### Deeper subclasses:

Class / Patent application number | Description | Number of patent applications / Date published |
---|---|---|

702016000 | Specific display system (e.g., mapping, profiling) | 67 |

20080262738 | Updating Information Regarding Sections of a Streamer That are in a Body of Water - To perform a marine survey, a streamer is deployed into a body of water, where the streamer has plural first sensors to perform a subterranean survey. Indications are received from second sensors in corresponding sections of the streamer, where the indications are regarding which sections are in the body of water. Information is updated regarding which sections of the streamer are in the body of water in response to the received indications. | 10-23-2008 |

20100114494 | Estimation of propagation angles of seismic waves in geology with application to determination of propagation velocity and angle-domain imaging - The invention relates to methods and computer-readable medium to implement computing the propagation velocity of seismic waves in the earth. The invention computes the true propagation velocity of seismic waves in the earth, which is a condition of obtaining an accurate image of subsurface geology that can be used to prospect for oil and gas deposits. In an embodiment, the method of computing the propagation velocity of seismic waves in earth, includes providing an estimate of the propagation velocity, generating a time shift gather using a depth migration at a plurality of locations of the earth, converting each of the time shift gathers to a semblance gather, transforming each semblance gather into a velocity gather whose energy peaks represent a root-mean-square average of the propagation velocity along the forward and backward path between earth's surface and a point of the subsurface geology, and converting the energy peaks to the propagation velocity. | 05-06-2010 |

20130080067 | 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. | 03-28-2013 |

20090187347 | VH Signal Integration Measure for Seismic Data - A method and system of processing seismic data includes acquiring three-component seismic data and combining horizontal components of the three-component seismic data to obtain a merged horizontal component. Frequency spectra are determined for the acquired three-component seismic data. A ratio of a vertical component of the seismic data to the merged horizontal component is determined. A V/H integration-measure is obtained from the integration of the area bounded by a selected minimum-amplitude value and the amplitude values greater than the selected minimum-amplitude value and the V/H integration-measure is stored in a form for display. | 07-23-2009 |

20090157322 | Systems and Methods For Enhancing a Seismic Data Image - Systems and methods for enhancing the resolution of a seismic data image displayed on a face of a sampling probe. The enhanced image represents a maximum resolution of at least a portion of the seismic data image. The seismic data image is enhanced by extracting seismic data that are perpendicular to a reflection surface that is closest to a center of the sampling probe and positioning the extracted seismic data in a visible planar face of the sampling probe. | 06-18-2009 |

20120116682 | ENERGY DENSITY AND STRESS IMAGING CONDITIONS FOR SOURCE LOCALIZATION AND CHARACTERIZATION - A method and system for processing synchronous array seismic data includes acquiring synchronous seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data propagation process is applied to the synchronized array measurements to obtain dynamic particle parameters associated with subsurface locations. A maximum energy density imaging condition is applied to the dynamic particle parameters to obtain imaging values associated with subsurface locations. Subsurface positions of energy sources are located from the relative maximum of a plurality of the imaging values associated with subsurface locations. | 05-10-2012 |

20120016592 | IMAGE DOMAIN SIGNAL TO NOISE ESTIMATE WITH BOREHOLE DATA - A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects. | 01-19-2012 |

20120016591 | TIME REVERSE IMAGING ATTRIBUTES WITH BOREHOLE DATA - A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects. | 01-19-2012 |

20120016590 | VH Reservoir Mapping with Synchronous Data - A method and system of detecting and mapping a subsurface hydrocarbon reservoir includes determining ratio data for a plurality of orthogonal spectral components of naturally occurring low frequency background seismic data. The ratio data may be compared, plotted, contoured and displayed as a subsurface hydrocarbon reservoir map or a hydrocarbon potential map. The ratio data may represent a vertical spectral component of the seismic data over a horizontal spectral component of the seismic data. The subsurface hydrocarbon reservoir map may include contouring the ratio data over a geographical area associated with the seismic data. | 01-19-2012 |

20100223012 | Method for Determination of Diffractor Locations at Sea Bottom for the Purpose of Attenuating Such Energy - Coherency analysis, such as semblance scan or stacking amplitude, is used to locate diffractors. Once the diffractors are located, noise energy originating from the diffractors is minimized. Locations of each diffractor are determined by comparing the lateral coherency of the received amplitudes that each assumed diffractor position generates. | 09-02-2010 |

20120035853 | UNIQUE COMPOSITE RELATIVELY ADJUSTED PULSE - The invention relates to acquiring seismic data in either land or marine environments, but typically marine environments where a pulse-type source is fired in a distinctive composite pulse like a distinctive rumble. In a preferred embodiment, a number of pulse-type seismic sources, sometimes called an array, are fired in a distinctive composite pulse to be able to identify within the returning wavefield the energy resulting from the composite pulse. Firing the pulse-type sources creates an identifiable signature so that two or more marine seismic acquisition systems with source arrays can be acquiring seismic data concurrently and the peak energy delivered into the water will be less, which will reduce the irritation of seismic data acquisition to marine life. | 02-09-2012 |

20100088035 | PSEUDO-ANALYTICAL METHOD FOR THE SOLUTION OF WAVE EQUATIONS - The instant invention is a method for numerically propagating waves or solving wave equations on a digital computer. This invention can be used to compute highly accurate solutions to the wave equation, in fact in some cases it computes the analytical solution, something previously considered impossible. The instant method can also propagate waves that are not described by differential equations, such as anisotropic scalar waves. The invention has the advantages that it is computationally efficient, accurate, and flexible. Of importance is the ability to propagate waves that simulate the P-wave arrivals in both isotropic and anisotropic media with a scalar as opposed to a vector equation. | 04-08-2010 |

20140129150 | METHOD FOR ACOUSTIC IMAGING OF THE EARTH'S SUBSURFACE USING NON-LINEAR SIGNAL GENERATION AND DETECTION - A method for seismic surveying includes disposing a plurality of seismic sensors in a selected pattern above an area of the Earth's subsurface. A seismic energy source is repeatedly actuated proximate the seismic sensors. A signal used to actuate the source comprises a linear chirp having a starting frequency and an ending frequency less than twice the starting frequency. Recorded signals are processed to generate an image corresponding to at least one point in the subsurface, the processing includes stacking recordings from each sensor for a plurality of actuations of the source, cross correlating the stacked signals with an expected signal generated by non linearities in the subsurface and beam steering a response of the seismic sensors such that the at least one point is equivalent to a focal point of a response of the plurality of sensors. | 05-08-2014 |

20120143510 | HIGH RESOLUTION ATTRIBUTES FOR SEISMIC DATA PROCESSING AND INTERPRETATION - A visualization method for the computation and display of seismic attributes from time-frequency spectral analysis enables high resolution investigation of 3D seismic data for the exploration of oil and gas. First, high frequency resolution time derivative or space derivative of the amplitude and phase spectra of time-windowed signals are computed. Second, the derivatives are transformed into seismic attributes that are suitable for seismic data processing or interpretation. Applications for the method are illustrated with graphical screen 3D volume displays of dip and azimuth, curvature and faults. Aside from providing high resolution these displays may improve the productivity of a seismic interpreter or data processor. | 06-07-2012 |

20090132170 | SEISMIC DATA PROCESSING AND VISUALIZATION - A method of processing seismic data includes storing in a single file structure a first type of data representing an inline location, a second type of data representing a crossline location, and a third type of data representing at least one of a depth and time, said first, second and third type of data each being associated with a horizon of a poststack seismic trace at a location defined by said inline location and said crossline location; and storing in said single file structure at least a fourth type of data representing an attribute associated with said horizon of said poststack seismic trace at said location. | 05-21-2009 |

20120029827 | INTERACTIVE STRUCTURAL RESTORATION WHILE INTERPRETING SEISMIC VOLUMES FOR STRUCTURE AND STRATIGRAPHY - A method for performing seismic interpretation of a subterranean formation by enabling dual-domain interpretation of seismic features in the present day depth domain and simultaneously in a structurally restored “mapped” seismic domain. Specifically, seismic interpretation is performed on structurally restored seismic volumes while concurrently viewing the interpretation results in the structural domain. This increases the interpretation confidence by improved correlation of structural deformed events to their pre-structurally deformed geometry. The method includes the ability to progressively remove structural deformation from the seismic volume, corresponding to moving back in geologic time. The interpretation can be performed in either domain (present-day structure or structurally restored to a defined geologic event), and the interpretation will be mapped to any other computed geologic age or present structural age. | 02-02-2012 |

20120215453 | DEVICE AND METHOD FOR MULTI-DIMENSIONAL COHERENCY DRIVEN DENOISING DATA - Computing device, computer instructions and method for denoising seismic data recorded with seismic receivers. The method includes receiving the seismic data recorded with the seismic receivers, wherein the seismic data is recorded in a time-space domain; applying with a computing device a high resolution transform to the seismic data in the time-space domain to obtain transformed seismic data in a different domain than the time-space domain, such that the method is amplitude preserving; determining regions of noise and regions of true signal in the transformed seismic data; scaling down the regions of noise; and reverse transforming the transformed seismic data to the time-space domain. | 08-23-2012 |

20090248313 | Wavefront-defined radon transform - A computer-implemented method for processing data includes accepting a first collection of traces corresponding to signals received over time due to reflection of seismic waves from subsurface structures. A Radon transform is defined with respect to a set of wavefront parameters of the seismic waves. The transform defines a summation of amplitudes of the seismic waves over trajectories defined by the wavefront parameters. | 10-01-2009 |

20090204332 | Method For Indexing A Subsurface Volume For The Purpose Of Inferring Geologic Information - A method of determining a horizon volume. In one embodiment, the horizon volume is determined from obtained seismic information, and maps the obtained seismic information onto a flattened volume such that in the flattened volume, horizons represented in the obtained seismic information are shifted to be substantially coplanar with a surface defined by the horizon volume as an estimate of a single chronostratigraphic time such that the parameters of the flattened volume include (i) a two-dimensional position in a surface plane, and (ii) a metric related to chronostratigraphic time. | 08-13-2009 |

20100161233 | Time Reverse Reservoir Localization - A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. These dynamic particle parameters are stored in a form for display. Maximum values of the dynamic particle parameters may be interpreted as reservoir locations. The dynamic particle parameters may be particle displacement values, particle velocity values, particle acceleration values or particle pressure values. The sensors may be three-component sensors. Zero-phase frequency filtering of different ranges of interest may be applied. The data may be resampled to facilitate efficient data processing. | 06-24-2010 |

20110082646 | Noise Attenuation in Passive Seismic 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. | 04-07-2011 |

20110153218 | DIPLET-BASED SEISMIC PROCESSING - Methods, systems and software for generating a multi-dimensional volume are disclosed. The methods include decomposing one or more original volumes into a collection of diplets, wherein each diplet comprises information about spatial location, orientation, amplitude, wavelet, acquisition configuration, and coherency. The methods further include migrating the collection of diplets using one or more of a velocity model or an anisotropic velocity model, and synthesizing one or more of the migrated diplets to an output multi-dimensional seismic volume. | 06-23-2011 |

20110071763 | SYSTEM AND METHOD FOR FAULT IDENTIFICATION - A system, which may be and/or may include a computer system, and method for identifying a fault patch position from a seismic data volume. The system and method may include defining an initial active surface in the seismic data volume; identifying one or more active surfaces by minimizing the value of a function for energy; tracking back the active surfaces to find a set of control points; and producing the fault patch position formed by the set of control points. | 03-24-2011 |

20100268471 | METHOD OF PROCESSING DATA OBTAINED FROM SEISMIC PROSPECTING - A method of processing data obtained from seismic prospecting of an earth formation, comprises obtaining data representing a multicomponent seismic signal from a multicomponent seismic receiver at a receiver location in an earth formation, in response to transmitting seismic waves into the earth formation; performing a wave-equation migration of the multicomponent seismic signal to obtain a seismic image of the earth formation, wherein the polarization of the seismic wave at the receiver location is taken into account and wherein a seismic image value at a point in the earth formation is calculated from a sum of products of a source field component for a particular dimension and a complex conjugated back propagated wave field component for the same dimension, summed over a plurality of dimensions. | 10-21-2010 |

20100262373 | METHODS AND SYSTEMS FOR MICROSEISMIC MAPPING - Methods and systems for the detection and localization of microseismic events are proposed which operate in real-time. Hypocenters in three spatial dimensions are provided along with an estimate of the event origin time. Sensor positions may be distributed in 3D space, and are not confined to linear arrays in vertical wells. A location of the event is approximated and a grid search, based on the approximate location of the event, is used to derive a residual function over a finer sampling followed by a gradient search of the residual function to optimize the location of the event. | 10-14-2010 |

20100004870 | Method of Joint Inversion of Seismic Data Represented on Different Time Scales - A method of constructing an image representative of a heterogeneous medium by a procedure of joint inversion of seismic data represented on different time scales having an application for underground reservoir exploration. Sequential inversion of the seismic data is performed so as to determine a first model from the seismic data expressed in a first time scale, and a second model from the seismic data expressed in the second time scale. A scale factor t | 01-07-2010 |

20140195162 | DEVICE AND METHOD FOR DE-BLENDING SIMULTANEOUS SHOOTING DATA - A device, medium and method for de-blending seismic data associated with a subsurface of the earth. The method includes a step of receiving seismic data “d” recorded with one or more land receivers, wherein the seismic data includes shot recordings generated by plural sources that are simultaneously actuated; a step of forming either a continuous receiver trace or trace segments from the received seismic data; a step of selecting plural overlapping spatial blocks that cover the surface shot locations; a step of assigning the shot recordings to the plural overlapping spatial blocks; a step of applying a mathematical technique to the recordings to determine de-blended data; and a step of generating an image of the subsurface based on the de-blended data. | 07-10-2014 |

20110118985 | CONSISTENT DIP ESTIMATION FOR SEISMIC IMAGING - Systems and methods perform consistent dip estimation for seismic imaging. An example system applies global consistency constraints during iterative volume dip estimation of a seismic volume to improve upon conventional dip estimation methods. With each iteration, the system applies single and joint dip constraints, checking local dip estimates for reciprocity, causality, consistency, and vertical and lateral continuity. At discontinuities in the seismic volume, local divergences are marked with a quality attribute. Upon convergence of the volume dip estimation, the volume may be rendered in 3D, including the discontinuities. In performing volume dip estimation, the system can also provide automatic horizon interpretation and automatic fault detection. | 05-19-2011 |

20110137569 | Method For Combining Seismic Data Sets - A method is disclosed for combining seismic data sets. This method has application in merging data sets of different vintages, merging data sets collected using different acquisition technologies, and merging data sets acquired using different types of sensors, for example merging hydrophone and geophone measurements in ocean bottom seismic data. In one embodiment, a desired data trace is to be determined from a set of measured data traces, and the following steps are applied: (a) model filters are constructed which express the deterministic relationship between the desired data trace and each available measured trace that depends on the desired data trace; (b) the noise properties associated with each measured data trace are determined; (c) a sufficient statistic for the desired data trace is formed by application of an appropriate filter to each measured trace and summing the filter outputs; (d) the sufficient statistic is further processed by a single-input single-output estimator to construct an estimate of the desired data trace from the sufficient statistic. | 06-09-2011 |

20090292476 | METHOD OF SEISMIC DATA INTERPOLATION BY PROJECTION ON CONVEX SETS - According to a preferred aspect of the instant invention, there is provided herein a system and method for Interpolation of seismic data with a POCS (projection onto convex sets) algorithm that can produce high quality interpolation results, at a reduced computational cost. In particular, optimizing the threshold calculations, allowing for aliased data, allowing the algorithm to skip unneeded Fourier transforms, and parallelization makes the method more practical and robust. Robust interpolation of aliased data may be done by limiting the calculations of the beginning iterations to the lowest temporal and spatial frequencies included in the data, then gradually allowing higher temporal and spatial frequencies into the following iterations. | 11-26-2009 |

20100161232 | Method For Geophysical and Geological Interpretation of Seismic Volumes using Chronological Panning - A computer-implemented method is provided for searching and analyzing a seismic data volume acquired in a seismic survey to determine potential for hydrocarbon accumulations in an associated subsurface region. Surfaces describing the seismic data volume are obtained. The surfaces are enumerated. At least one enumerated surface is selected. The at least one selected surface is augmented when the selected surface does not substantially cover an area associated with the seismic data volume. The augmenting is performed until all selected surfaces substantially cover the area. The at least one selected surface is displayed, with geologic or geophysical data associated therewith, for visual inspection or interpretation, or saving digital representations thereof to computer memory or data storage. | 06-24-2010 |

20120072117 | SYSTEM AND METHOD FOR GENERATING IMAGES OF SUBSURFACE STRUCTURES - A system and method for generating images of a subsurface region of interest is provided. In one embodiment, a computer-implemented method of generating images related to a subsurface region of interest includes: accessing, via a central processing unit (CPU), seismic data and an earth model related to the subsurface region of interest; forward propagating a source wavefield using the earth model at a first time interval via at least one external co-processor coupled to the CPU; transferring, at a second time interval, the forward propagated source wavefield to the CPU for compression and external storage; backward propagating the seismic data at the first time interval via the external co-processor to derive backward propagated receiver wavefield; and transferring, at the second time interval, the backward propagated receiver wavefield to the CPU. Via the CPU, the method further includes retrieving the stored forward propagated source wavefield; decompressing the retrieved forward propagated source wavefield; and applying imaging conditions to the decompressed forward propagated source wavefield and backward propagated receiver wavefield to construct image data representative of the subsurface region of interest. | 03-22-2012 |

20120022791 | VH Reservoir Mapping with Borehole Sensors - A method and system of detecting and mapping a subsurface hydrocarbon reservoir includes determining ratio data for a plurality of orthogonal spectral components of naturally occurring low frequency background seismic data. The ratio data may be compared, plotted, contoured and displayed as a subsurface hydrocarbon reservoir map or a hydrocarbon potential map. The ratio data may represent a vertical spectral component of the seismic data over a horizontal spectral component of the seismic data. The subsurface hydrocarbon reservoir map may include contouring the ratio data over a geographical area associated with the seismic data. | 01-26-2012 |

20140019057 | Microseismic Event Verification Using Sub-stacks - Disclosed herein are various embodiments of discriminating between small microseismic events and false events comprising identifying candidate events, and creating sub-stacks of the microseismic data traces. Analysis of the sub-stacks shows distinct differences between real microseismic events and false events created by noise bursts. Further discrimination between real and false events is achieved by visual or automated analysis of the reverberations and patterns of polarity reversal associated with real microseismic events, which are more clearly visible in the sub-stacks than in the raw microseismic data. The methods described herein are applicable to surface, downhole and buried array microseismic data. | 01-16-2014 |

20120059592 | TRACING SEISMIC SECTIONS TO CONVERT TO DIGITAL FORMAT - Method, system, and computer program product for tracing seismic sections to convert to digital format are provided. The method includes: receiving a scan of a seismic section having multiple overlapping traces measured at spot points; splitting the traces into segments; associating the segments with appropriate baselines; estimating the traces between segments using logical rules; and deriving amplitudes of the traces. | 03-08-2012 |

20110093203 | SYSTEM AND METHOD FOR CLUSTERING ARRIVALS OF SEISMIC ENERGY TO ENHANCE SUBSURFACE IMAGING - Seismic data acquired at or near a geologic volume of interest is processed. This may include forming an image of the geologic volume of interest from the seismic data. The seismic data may be processed by aggregating energy arrivals to reduce the number of imaging processes that must be performed to determine an image of the geologic volume of interest. This aggregation may be based on groupings of energy arrivals referred to herein as clusters. | 04-21-2011 |

20120253682 | SEISMIC SURVEY METHOD OF THE SUBSOIL - A method for obtaining a volumetric image of a geological structure in the subsoil includes generating a plurality of seismic waves by plural seismic sources, acquiring signals or traces obtained by processing the seismic waves reflected by the geological structure for creating a seismic record or shot gather for the activation position of each seismic source, migrating, through a numerical processing, each shot gather to create a respective partial volumetric image of the geological structure, summing the single partial volumetric images to obtain the overall volumetric image of the geological structure, the summing of the single partial volumetric images being obtained by grouping the seismic sources into groups, grouping the groups of seismic sources into super-groups, and effecting N migrations for each super-group. | 10-04-2012 |

20100036614 | Locating oil or gas passively by observing a porous oil and gas saturated system giving off its characteristic resonance response to ambient background noise, including optional differentiation of oil, locatinggas and water - This patent deals with methods to extract and analyze seismic signals due to resonance phenomena in an enclosed oil, gas, or water reservoir, which are passively excited by seismic background noise, locating thereby the presence of the reservoir by doing qualitative and quantitative estimates via forward modeling. Measurements are first used in a qualitative analysis in eight steps. The influence of gas bubbles is important. A quantitative method in form of a numerical simulation using one of several specific physical concepts is used for further analysis. By using successive forward modeling, together with investigation and feedback and in conjunction with the Monte Carlo method, more details are gained. It is also possible to determine the fluid type. The uniqueness of the methods is first that it is purely passive; second it is directly sensitive to the oil or gas, because the resonance effect is only present for a fluid. | 02-11-2010 |

20110130967 | METHOD OF CORRECTING AMPLITUDES IN VIRTUAL SOURCE IMAGING OF SEISMIC DATA - A method for imaging a subsurface formation using at least two seismic sources and receivers comprises: a) creating a wave field in the formation, b) obtaining a set of responses for each receiver and performing wave field separation on them, c) obtaining a virtual source signal for at least a first receiver k by cross-correlating at least part of the response of a second receiver m with at least part of the response of the first receiver k and summing the cross-correlated responses from the sources, making receiver k a virtual source, d) for each virtual source, estimating an amplitude radiation pattern by performing a transform of the response data, e) deconvolving at least one virtual source signal with at least part of the estimated radiation pattern for that receiver to produce an amplitude-corrected virtual source signal, and f) using that signal to create an image of the subsurface formation. | 06-02-2011 |

20140012508 | METHOD AND APPARATUS FOR ANALYZING DATA IN TIME-LAPSE GEOPHYSICAL SURVEYS - Methods and apparatuses are disclosed that assist in correlating subsequent geophysical surveys. In some embodiments, geophysical data may be generated including a first set of data from a monitor survey that is matched with a second set of data from a baseline survey. An attribute value may be generated for each datum in the first set of data and each attribute value generated may be stored with its corresponding datum. Then, the first set of data may be processed based on the stored attribute values. In some embodiments, the attribute values may be based upon the geometric closeness of sources and receivers in the baseline and monitor surveys. | 01-09-2014 |

20120221248 | METHODS 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. | 08-30-2012 |

20100299071 | METHOD OF PROCESSING DATA OBTAINED FROM SEISMIC PROSPECTING - A method of calculating a seismic noise image for a formation comprises the steps of: a) obtaining data representing a multicomponent seismic signal from at least one receiver, in response to transmitting seismic waves into the formation; b) obtaining a velocity model of the earth formation; c) determining a plurality of wave field components; d) obtaining a set of second components; e) obtaining, for each subsurface point, at least two products, each product comprising the product of a selected wave field component and a different second component; and f) and generating a noise image by calculating at least one difference between different products for at least one image point. | 11-25-2010 |

20120316792 | RTM SEISMIC IMAGING WITHOUT SCRATCH DATA STORAGE SYSTEM AND METHOD - A system, method and computer program product for seismic imaging implements a seismic imaging algorithm utilizing Reverse Time Migration technique requiring large communication bandwidth and low latency to convert a parallel problem into one solved using massive domain partitioning. Several aspects of the imaging problem, including very regular and local communication patterns, balanced compute and communication requirements, scratch data handling and multiple-pass approaches. The partitioning of the velocity model into processing blocks allows each sub-problem to fit in a local cache, increasing locality and bandwidth and reducing latency. | 12-13-2012 |

20140142859 | EFFICIENT WAVEFIELD COMPRESSION IN SEISMIC IMAGING - A system, method and computer program product for seismic imaging implements a seismic imaging algorithm utilizing Reverse Time Migration (RTM) and Full Waveform Inversion (FWI) techniques requiring large communication bandwidth and low latency to convert a parallel problem into one solved using massive domain partitioning. Since in RTM and FWI, the forward wave propagation is iteratively calculated on time step increments, there are very high statistical correlation between the intermediate wavefields at the adjacent time steps. This correlation is exploited in compression of the intermediate wavefields so as to achieve much higher compression ratio and avoid the disk IO bottleneck and reduce the overall computing time substantially. Further, during simulation of a reverse wavefield, reverse predictive encoding technique is performed such that snapshots are not recovered in the reverse propagation path due to a prediction chain. | 05-22-2014 |

20140142860 | EFFICIENT WAVEFIELD COMPRESSION IN SEISMIC IMAGING - A system and computer program product for seismic imaging implements a seismic imaging algorithm utilizing Reverse Time Migration (RTM) and Full Waveform Inversion (FWI) techniques requiring large communication bandwidth and low latency to convert a parallel problem into one solved using massive domain partitioning. Since in RTM and FWI, the forward wave propagation is iteratively calculated on time step increments, there are very high statistical correlation between the intermediate wavefields at the adjacent time steps. This correlation is exploited in compression of the intermediate wavefields so as to achieve much higher compression ratio and avoid the disk IO bottleneck and reduce the overall computing time substantially. Further, during simulation of a reverse wavefield, reverse predictive encoding technique is performed such that snapshots are not recovered in the reverse propagation path due to a prediction chain. | 05-22-2014 |

20120271550 | Seismic Imaging Systems and Methods Employing a 3D Reverse Time Migration with Tilted Transverse Isotropy - 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. | 10-25-2012 |

20110238315 | Method of imaging the subsurface using stacked seismic data from azimuthally varying velocity and amplitude information - Fast anisotropy axis values are determined for each bin in seismic data binned by azimuth. A fast azimuth gather is determined within each bin in the seismic data from the fast anisotropy axis values. The earth's subsurface is imaged, using the fast azimuth gathers. | 09-29-2011 |

20120290214 | COUPLED TIME-DISTANCE DEPENDENT SWEPT FREQUENCY SOURCE ACQUISITION DESIGN AND DATA DE-NOISING - Acquisition of data by managing crosstalk interference with sector designs and unique sweeps is conducted and the resultant data are processed in 3D common receiver domain to attenuate crosstalk noise while preserving the signals for high source and receiver density acquisition designs. High-amplitude spectral amplitudes are attenuated and inter-ensemble statics or structural time delays are applied to achieve optimum filter performance. If the spectral amplitudes have been attenuated to a level consistent with non-simultaneous acquisition, conventional surface consistent processing can be performed to correct for statics and amplitude variations. A 3-point filter in different frequency bands may then be applied to remove any remaining residual crosstalk noise. | 11-15-2012 |

20100161234 | Time Reverse Reservoir Localization - A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. These dynamic particle parameters are stored in a form for display. Maximum values of the dynamic particle parameters may be interpreted as reservoir locations. The dynamic particle parameters may be particle displacement values, particle velocity values, particle acceleration values or particle pressure values. The sensors may be three-component sensors. Zero-phase frequency filtering of different ranges of interest may be applied. The data may be resampled to facilitate efficient data processing. | 06-24-2010 |

20110270526 | UPDATING INFORMATION REGARDING SECTIONS OF A STREAMER THAT ARE IN A BODY OF WATER - To perform a marine survey, a streamer is deployed into a body of water, where the streamer has plural first sensors to perform a subterranean survey. Indications are received from second sensors in corresponding sections of the streamer, where the indications are regarding which sections are in the body of water. Information is updated regarding which sections of the streamer are in the body of water in response to the received indications. | 11-03-2011 |

20100286919 | Characterizing Spatial Variability of Surface Waves In Seismic Processing - Embodiments use seismic processing methods that account for the spatial variability of surface wave velocities. Embodiments analyze surface wave properties by rapidly characterizing spatial variability of the surface waves in the seismic survey data ( | 11-11-2010 |

20110295510 | Active Noise Injection Computations for Improved Predictability in Oil and Gas Reservoir Characterization and Microseismic Event Analysis - Application of nonlinear resonance interferometry is introduced as a new geophysical approach to improve predictability in characterization of subsurface microseismic event analysis and propagation of fracture. In contrast to reflection methods that remove random information noise, nonlinear resonance interferometry exploits the full microseismic acquisition spectrum. In some examples, systems and techniques implement novel computational interactions between acquired microseismic wavefield attributes and a nonlinear system in software to amplify distortions in microseismic noise and exploits injection of synthetic noise, in software format, to fracture events. | 12-01-2011 |

20140095078 | METHOD AND SYSTEM FOR PRESENTING SEISMIC INFORMATION - The present invention relates to a method for presenting seismic information sampled from geological formations, including the steps of sampling information from a chosen geological formation representing at least one parameter related to the formation, analyzing the sampled information from said geological formation producing a measure of the uncertainty related to said at least one parameter, and thereby defining a geobody related to said uncertainty of the at least one parameter being less than a predetermined limit. | 04-03-2014 |

20120290213 | FREQUENCY-VARYING FILTERING OF SIMULTANEOUS SOURCE SEISMIC DATA - Seismic data acquired by independent simultaneous sweeping (ISS®) techniques are processed is to attenuate random uncompressed cross-talk signals and improve the resolution of the pre-stack migrated time image. A frequency-varying mean filter is applied on cross-spread offset-azimuth gathers of the data. The frequency-space domain filter may vary its window size according to the characteristics of the cross-talk. | 11-15-2012 |

20120029828 | CHRONO-STRATIGRAPHIC AND TECTONO-STRATIGRAPHIC INTERPRETATION ON SEISMIC VOLUMES - A method for performing chrono-stratigraphic interpretation of a subterranean formation. The method includes obtaining a seismic volume containing stratigraphic features of the subterranean formation deformed by structural events, performing structural restoration of the seismic volume to generate a restored seismic volume by removing deformation due to the structural events, performing a chrono-stratigraphic interpretation based on the restored seismic volume to generate chrono-stratigraphic objects each associated with a respective relative geologic age, and displaying the chrono-stratigraphic objects in a chrono-stratigraphic space according to the respective relative geologic age of each of the stratigraphic objects. | 02-02-2012 |

20100153015 | VH reservoir mapping - A method and system of detecting and mapping a subsurface hydrocarbon reservoir includes determining ratio data for a plurality of orthogonal spectral components of naturally occurring low frequency background seismic data. The ratio data may be compared, plotted, contoured and displayed as a subsurface hydrocarbon reservoir map or a hydrocarbon potential map. The ratio data may represent a vertical spectral component of the seismic data over a horizontal spectral component of the seismic data. The subsurface hydrocarbon reservoir map may include contouring the ratio data over a geographical area associated with the seismic data. | 06-17-2010 |

20110218737 | Active Noise Injection Computations for Improved Predictability in Oil and Gas Reservoir Discovery and Characterization - Application of nonlinear resonance interferometry is introduced as a new geophysical approach to improve predictability in characterization of subsurface porosity, rock and fluid properties. In contrast to reflection methods that remove random information noise, nonlinear resonance interferometry exploits the full seismic acquisition spectrum to assess how low frequency and high-frequency noise is differentially and directly modulated by varying levels of porosity and hydrocarbon content in the lithologies of interest. In some examples, systems and techniques implement novel computational interactions between acquired seismic wavefield attributes and a nonlinear system in software to amplify distortions in seismic noise and exploits injection of synthetic noise, in software format, to detect hydrocarbon traps and lithology changes at spatial scales below seismic resolution, thereby increasing the information value of low-resolution data. The techniques are broadly applicable to de-risking conventional clastic and carbonate reservoirs and non-conventional shale gas resource prospects. | 09-08-2011 |

20130030709 | ATTENUATING SEA-SURFACE GHOST WAVE EFFECTS IN SEISMIC DATA - 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. | 01-31-2013 |

20140100786 | Analyzing Microseismic Data from a Fracture Treatment - Systems, methods, and software can be used to analyze microseismic data from a fracture treatment. In some aspects, data for a new microseismic event are from a fracture treatment of a subterranean zone. An updated parameter for a fracture plane is calculated. The fracture plane was previously generated based on data for prior microseismic events. The updated parameter calculated is calculated based on the data for the new microseismic event and the data for the prior microseismic events. A graphical representation of the fracture plane is displayed based on the updated parameter. | 04-10-2014 |

20090204331 | Method For Determining Geological Information Related To A Subsurface Volume Of Interest - A method of determining geological information related to a subsurface volume. In one embodiment, the method comprises obtaining a seismic information related to a subsurface volume; determining a horizon volume that automatically maps the seismic information into a flattened volume, wherein one axis of the flattened volume corresponds to chronostratigraphic time, and wherein horizons represented by the seismic information are automatically accounted for in the horizon volume, and are shifted by the horizon volume into the flattened volume to be substantially planar and substantially perpendicular to the axis of the flattened volume that corresponds to chronostratigraphic time; determining a derivative of the horizon volume with respect to chronostratigraphic time; and determining geological information related to the subsurface volume based on the derivative of the horizon volume with respect to chronostratigraphic time. | 08-13-2009 |

20080288173 | Seismic attributes for reservoir localization - A method and system for processing three component seismic data includes determining a covariance data matrix from three component seismic data for each of a plurality of time periods to obtain eigenvectors and eigenvalues. One or more seismic attributes are calculated from the eigenvectors and eigenvalues for each of a plurality of time periods. A stability measure is determined from the calculated seismic attribute for each of the plurality of time periods and stored for display. | 11-20-2008 |

20130138351 | Method and System of Plotting Values Indicative of Characteristics of an Underground Formation - Plotting values indicative of characteristics of an underground formation. At least some of the illustrative embodiments include: obtaining a plurality of values indicative of characteristics of an underground formation; and plotting the plurality of values on an output device of a computer system. The plotting may further include: plotting parallel to a first axis a first plurality of symbols where each symbol is indicative of a value of a characteristic of a first portion of the underground formation, location of the first plurality of symbols with respect to the first axis is indicative of a first parameter, and location of the first plurality of symbols with respect to a second axis is indicative of a second parameter distinct from the first parameter; and wherein location of at least one symbol with respect to the first axis is also indicative of a third parameter, different than the first and second parameters. | 05-30-2013 |

20130138350 | ENHANCED TERMINATION IDENTIFICATION FUNCTION BASED ON DIP FIELD GENERATED FROM SURFACE DATA - A method for determining stratigraphic termination points from a seismic dataset, includes: deriving extremal surfaces from the seismic dataset, wherein the extremal surfaces include points that are each associated with at least one of a dip magnitude and a dip azimuth; selecting a subset of points on the extremal surfaces that meet a predetermined criterion; identifying, using a processor, a set of dip deflection points from the subset of points; defining a termination zone from the dip deflection points; defining extremal surfaces that are associated with the termination zone as associated surfaces; and determining the stratigraphic termination points based on the associated surfaces. | 05-30-2013 |

20110276273 | IMAGE DOMAIN SIGNAL TO NOISE ESTIMATE - A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects. | 11-10-2011 |

20110276272 | TIME REVERSE IMAGING ATTRIBUTES - A method and system for processing synchronous array seismic data includes acquiring synchronous passive seismic data from a plurality of sensors to obtain synchronized array measurements. A reverse-time data propagation process is applied to the synchronized array measurements to obtain a plurality of dynamic particle parameters associated with subsurface locations. Imaging conditions are applied to obtain imaging values that may be summed or stacked to obtain a time reverse image attribute. A volume of imaging values may be scaled by a non-signal noise function to obtain a modified image that is compensated for noise effects. | 11-10-2011 |

20140163890 | METHOD AND SYSTEM FOR PRESENTING SEISMIC INFORMATION - The present invention relates to a system mapping geological formations related to seismic studies comprising interrogation means for sampling information from geological features in a mapped area, e.g. through seismic sampling methods, the sampled information being stored in association with a position related to the sampled information providing a mapping of the area, wherein the system also comprises analyzing means for obtaining attribute information related to the sampled information in each position and storing said attribute information associated to said positions so as to provide an ensemble of attribute values related to the mapped area subject to the seismic studies. | 06-12-2014 |

20140172308 | REPEATABILITY INDICATOR BASED ON SHOT ILLUMINATION FOR SEISMIC ACQUISITION - Methods and systems for similarity indicator calculation associated with seismic data acquisition are described. A similarity indicator value can, for example, be based on a normalized partitioned intensity uniformity (PIU) metric. In another aspect, shot imprints are compared by mapping a base (reference) shot imprint onto a current sample of a shot imprint before calculating the similarity indicator value. The similarity indicator value is associated with the shot imprint location used in the calculation and allows re-shooting of only the areas where an insufficient quality of shot data is detected based on a preconfigured threshold value for the similarity indicator. | 06-19-2014 |