Abstract: Method for estimating a model of seismic velocity in a subsurface region from seismic data (31) recorded on 3-component instruments. The method measures the apparent incidence angle (32) of a seismic wave observed at a surface as a function of wave frequency. This apparent angle is converted to an effective velocity as a function of frequency (33), which is then inverted (34) to obtain a subsurface velocity model.

Abstract: Seismic image filtering machines, systems, program products, and computer implemented methods are provided to generate a filtered seismic image responsive to filtered seismic image data generated by attenuating coherent seismic noise from surface waves of an unfiltered wavefield constructed from unfiltered seismic image data through a single downward extrapolation of the unfiltered wavefield using a plurality of nonstationary convolution operators to perform localized filtering at each of a plurality of spatial locations of the unfiltered wavefield. Various embodiments, for example, can beneficially handle strong lateral velocity variations thus making various embodiments effective tools to remove complicated coherent seismic noise which is typically in the form of exponentially decaying evanescent waves.

Abstract: A stable method for using fat-ray tomography to determine a high-resolution velocity model of the subsurface from seismic data (71). The velocity model (72) may be used in migrating the seismic data (76) to image the subsurface. Rays are traced from a subsurface reflection point to surface source and receiver locations (73), using Fresnel zone construction methods (74) that honor correct initial conditions, with the Fresnel radius being a function of velocity.

Abstract: A system and method for subsurface characterization including depth and structural uncertainty estimation is disclosed. In one embodiment, the method may include determining a detectability threshold for moveout in a seismic data gather based on the seismic data and computing a depth uncertainty function, wherein the depth uncertainty function represents an error estimate that is used to analyze an interpretation of the seismic data. In another embodiment, the method may include receiving a depth uncertainty volume and at least one interpreted horizon from seismic data, extracting a depth uncertainty cage for each of the interpreted horizons based on the depth uncertainty volume, and simulating multiple realizations for each of the interpreted horizons, constrained by the depth uncertainty cage. The multiple realizations may be used for analyzing changes to geometrical or structural properties of the at least one interpreted horizon.

Abstract: A method for adjusting an isotropic depth image based on a mis-tie volume is provided. The method generally includes obtaining an isotropic velocity volume for a geophysical volume, obtaining an isotropic depth image of the geophysical volume, obtaining time-depth pairs at downhole locations in the geophysical volume, generating mis-tie values based on the time-depth pairs and the isotropic velocity volume, assigning uncertainties to the mis-tie values, generating a smoothest mis-tie volume that satisfies a target goodness of fit with the mis-tie values. Adjustment of the isotropic depth image may be achieved based on the mis-tie volume or a calibration velocity obtained from the mis-tie volume.

Abstract: A container data center includes a container, a plurality of power supplies, an electric switch system, a plurality of normally closed switches, an alarm device, and a controller. The electric switch system is received in the container. The plurality of normally closed switches are connected between the power supplies and the electric switch system. Each normally closed switch is connected with a corresponding one of the power supplies in series. The controller is connected to the normally closed switches and the alarm device, configured for receiving earthquake information containing an earthquake intensity, and configured for controlling the alarm device to activate alarms and controlling some of the normally closed switches or all the normally closed switches to open when the earthquake intensity is equal to or greater than a predetermined earthquake intensity.

Abstract: A method for determining values of anisotropic model parameters of a Tilted Transversely Isotropic (TTI) Earth model, the method including obtaining an initial TTI earth model that substantially flattens common-imaging-point gathers and substantially ties seismic data to well data; inputting checkshot data and/or VSP data to determine updated values of Vp0 near the well locations; determining an incremental improvement ??; extrapolating the relative change ?? from near-well locations to the entire three dimensional TTI earth model; determining updated values of Vp0=Vp0 (1???); inputting near-to-mid-offset/angle and mid-to-far-offset/angle residual moveout information; and providing updated values of ? and ?.

Abstract: Systems and methods are provided for detecting subterranean properties associated with a geological domain. One example method may comprise obtaining waveform information corresponding to a geological domain. The method may further comprise performing a global inversion on the waveform information. Furthermore, the method may comprise performing a deterministic inversion on the waveform information. The method may also comprise determining one or more subterranean properties associated with the geological domain based at least in part on the global inversion and the deterministic inversion.

Abstract: A disclosed direct velocity seismic sensor includes a housing, a proof mass suspended in the housing by a resilient component, and a motion dampener that damps oscillation of the proof mass to a degree that displacement of the proof mass relative to the housing is substantially linearly proportional to a rate of change of seismic displacements of the housing over a frequency range of interest. A described method for constructing a seismic sensor includes using a calculated resonant frequency to determine a damping factor that causes the displacement of the proof mass to be substantially proportional to the rate of change of seismic displacement of the housing. One illustrative disclosed system includes an optical velocity sensor and a detector where a light beam produced by the velocity sensor and a reference beam interfere at the detector, and the detector produces a signal indicative of a velocity experienced by the velocity sensor.

Abstract: The present disclosure relates to determining the attenuation of an electromagnetic signal passing through a conductive material. An antenna is provided and placed in relatively close proximity to the conductive material. An alternating current is passed through the antenna and the impedance of the antenna is measured. The attenuation is determined using the measured impedance. A single frequency measurement may be made, or multiple measurements using different frequencies may be made. Grouped parameters based on properties of the material and the frequency of the current are used to relate the coil impedance to the attenuation. A current frequency for which the ratio of the antenna's resistive part of the impedance to the angular frequency of the current is substantially insensitive to at least one of the parameters is preferred.

Abstract: Recorded seismic data are represented as a convolution of operators representing a reflectivity series of the earth and a seismic wavelet. The recorded seismic wavelet is represented as a convolution of operators representing a receiver ghost, a source ghost, a ghost-free source system response, an earth filter response, and a receiver system response. The operator representing the receiver ghost is removed from the convolution representing the seismic wavelet. The operator representing the source ghost is removed from the convolution representing the seismic wavelet. The operator representing the ghost-free source response is removed from the convolution representing the seismic wavelet. The operator representing the earth filter response is removed from the convolution representing the seismic wavelet. The operator representing the seismic wavelet is removed from the convolution representing the recorded seismic data.

Abstract: A method for adjusting an isotropic depth image based on a mis-tie volume is provided. The method generally includes obtaining an isotropic velocity volume for a geophysical volume, obtaining an isotropic depth image of the geophysical volume, obtaining time-depth pairs at downhole locations in the geophysical volume, generating mis-tie values based on the time-depth pairs and the isotropic velocity volume, assigning uncertainties to the mis-tie values, generating a smoothest mis-tie volume that satisfies a target goodness of fit with the mis-tie values. Adjustment of the isotropic depth image may be achieved based on the mis-tie volume or a calibration velocity obtained from the mis-tie volume.

Abstract: A method to correct errors in a conversion from time gather to angle gather using slant stacks wherein the slant stacking is performed along a direction that is normal to a dip or along three orthogonal directions. The slant stacking is performed in various domains.

Abstract: The application discloses a process and apparatus for characterising the evolution of a reservoir by co-analyzing the changes in the propagation times and seismic amplitudes of seismic reflections. The method comprising the steps of: providing a base survey of the reservoir with a set of seismic traces at a first time; and providing a monitor survey of the reservoir, taken at a second time, with a set of seismic traces associated to the same positions as in the base survey. The evolution of the reservoir is then characterised by inversion to obtain an estimate of the changes having occurred in the time interval between base and monitor surveys, the inversion being performed using at least some seismic traces for which no assumption is made that the energy is propagating vertically. In a main embodiment, inversion is performed by minimising a function which includes a term dependent on the incident angle of the seismic reflections.

Abstract: A technique includes receiving seismic data acquired in a seismic survey in the vicinity of a reflecting interface. The survey has an associated undersampled direction. The technique includes providing second data indicative of discrete samples of incident and reflected components of a continuous seismic wavefield along the undersampled direction and relating the discrete samples to a linear combination of the continuous incident and reflected seismic wavefields using at least one linear filter. Based on the relationship, an unaliased representation of the linear combination of the continuous incident and reflected seismic wavefields is constructed.

Abstract: A system and method are described herein for generating a velocity model of returned seismic signals for under-ocean floor environments. The system and method generate a series of source signals, receive a corresponding set of direct signals, reflected signals, and refracted signals, solve a velocity model equation using a full waveform inversion function with respect to the received set of direct signals, reflected signals and refracted signals to minimize a least square misfit function by relaxing a dependency on low frequency reflections in the full waveform inversion function. The system and method then generate the velocity model based on the solution to the velocity model equation, and display the velocity model.

Abstract: A method of forming a geological model of a region of the earth includes obtaining seismic data relating to the region, the seismic data including seismic traveltime uncertainty. A seismic velocity model of the region may also be provided and includes velocity uncertainty. Three dimensional positions of a plurality of points of the region can then be determined. The three dimensional positional uncertainties of at least some of the points can be calculated from the traveltime uncertainty and the velocity uncertainty. This can be combined with the positions to form a geological model.

Abstract: A method for the detection and localization of microseismic events is proposed which operates in real-time. It provides hypocenters in three spatial dimensions 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. The method combines and improves two existing approaches. For detection and localization purposes the method makes use of the generalized beam-forming and forward modeling properties defined in the “CMM” algorithm. For location refinement, the method uses a stabilized version of the generalized “Geiger” approach.

Abstract: A method of processing geophysical data including at least measured potential field data from a potential field survey of a surveyed region of the earth to provide a representation of the geology of said surveyed region, the method comprising generating a first model of said surveyed region by fitting data predicted by said first model to said measured data for a specified frequency range; predicting full range potential field data for all measured frequencies using said generated first model; comparing said full range predicted data to said measured potential field data to provide full range residual data representing a difference between the full range predicted data and the full range measured data, and interpreting said full range residual data to provide a representation of said geology of said surveyed region.

Abstract: The invention relates to a method for determining, for a detector placed on the surface of the seabed, the vertical propagation time and the velocity of propagation in the water of a wave emitted from an emission point. The method includes: emitting a wave from the emission point; recording the wave received by the detector; determining the vertical propagation time by, where tdir is the direct wave propagation time between the emission point and the detector, and tmul is the propagation time of the first multiple wave between the emission point and the detector; and determining the velocity of propagation of the wave, where X is the distance between the emission point and the water-surface point that is vertical to the detector.

Abstract: A characteristic of a target layer is determined by receiving primary wave data and secondary wave data from multi-component receivers for acquiring both primary wave data and secondary wave data in a seismic exploration system, calculating a Vp/Vs ratio by correlating in a frequency domain a number of estimated primary wave spectra derived from a measured secondary wave spectrum to a measured primary wave spectrum, wherein Vp is a first velocity of a primary wave and Vs is a second velocity of a secondary wave for a target depth interval, using a warp factor associated with the Vp/Vs ratio, calculating a time separation for primary wave signals from a top and a bottom of the target depth interval.

Abstract: Method, computer device and software for calculating a corrected temporal variation (dt1)depth or a corrected relative temporal variation (dt1/t1)depth of a first body wave based on a second body wave. The method includes receiving raw seismic data recorded with a receiver; calculating arrival-time variations for the first and second body waves; calculating first and second relative temporal variations for the first and second body waves; and correcting the first relative temporal variation based on the second relative temporal variation to obtain the corrected relative temporal variation or correcting the first temporal variation based on the second temporal variation to obtain the corrected temporal variation. The second wave is either a body wave or a surface wave.

Abstract: Method, computer device and software for calculating a corrected temporal variation (dt1)depth or a corrected relative temporal variation (dt1/t1)depth of a first body wave based on a second body wave. The method includes receiving raw seismic data recorded with a receiver; calculating arrival-time variations for the first and second body waves; calculating first and second relative temporal variations for the first and second body waves; and correcting the first relative temporal variation based on the second relative temporal variation to obtain the corrected relative temporal variation or correcting the first temporal variation based on the second temporal variation to obtain the corrected temporal variation. A body wave is a wave that experiences at least one reflection before being recorded by the receiver.

Abstract: For determining an impact index which indicates the image or damage caused by an earthquake to a portfolio, an equation is stored for calculating a local earthquake intensity for a geographical location. The portfolio includes geographical locations and individual weighting factors assigned to the geographical locations. Furthermore, for the geographical locations stored are one or more impact ratio tables including impact ratios for different earthquake intensity levels. The impact index is calculated for the geographical locations by determining in each case the impact ratio for the local intensity at the respective geographical location, and adding up the impact ratios weighted in each case by the weighting factor assigned to the respective geographical location. An impact index that reflects the geographical distribution of the portfolio can be determined, without the need for a network of seismological measurement stations associated with the geographical locations.

Abstract: A method of forming a geological model of a region of the earth includes obtaining seismic data relating to the region, the seismic data including seismic traveltime uncertainty. A seismic velocity model of the region may also be provided and includes velocity uncertainty. Ray tracing may be performed on the seismic data using the velocity model to determine the three dimensional positions of a plurality of points of the region. The three dimensional positional uncertainties (7-12) of at least some of the points can be calculated from the traveltime uncertainty, the velocity uncertainty, and uncertainty in the ray propagation direction. This can be combined with the positions determined by the ray tracing to form a geological model.

Abstract: A method and apparatus for estimating velocity in a subsurface region. Seismic data for a subsurface region may be received. One or more attributes for the seismic data may be calculated. A posterior distribution may be generated. The posterior distribution may represent one or more probabilities of one or more velocities for the attributes. A velocity with uncertainty may be determined for the subsurface region based on the posterior distribution. A pore pressure with uncertainty may be determined based on the velocity with uncertainty.

Abstract: A walkaway VSP survey is carried out using a receiver array. Using a vertical VSP survey and arrival times of surface multiples on the walkaway VSP, vertical interval velocities and the anisotropy parameters ? and ? are estimated. This may then be used to process surface seismic data to do a prestack depth migration of surface seismic data and used for interpretation. For multi-azimuthal walkaway or 3D VSP data, we determine two VTI parameters ? and ? for multi-azimuth vertical planes. Then we determine five anisotropic interval parameters that describe P-wave kinematics for orthorhombic layers. These orthorhombic parameters may then be used to process surface seismic data to give a stacked image in true depth and for the interpretation purposes.

Abstract: In at least some embodiments, the system obtains shot gathers for a survey region and migrates the shot gather data with an initial velocity model to obtain angle-domain common image gathers. The system processes the common image gathers to determine depth residuals and corresponding angle-dependent time deviations throughout a seismic survey region. The system solves a set of tomographic equations which employ ray theory to establish a relationship between a travel time deviation and the depth residual of a reflector in the depth-offset ray parameter (z,p) domain. The resulting updates are applied to the velocity model and can be used to re-migrate the shot gather data. The system generates a representation of the survey region that can be displayed to a user.

Abstract: A system and method for subsurface characterization including depth and structural uncertainty estimation is disclosed. In one embodiment, the method may include determining a detectability threshold for moveout in a seismic data gather based on the seismic data and computing a depth uncertainty function, wherein the depth uncertainty function represents an error estimate that is used to analyze an interpretation of the seismic data. In another embodiment, the method may include receiving a depth uncertainty volume and at least one interpreted horizon from seismic data, extracting a depth uncertainty cage for each of the interpreted horizons based on the depth uncertainty volume, and simulating multiple realizations for each of the interpreted horizons, constrained by the depth uncertainty cage. The multiple realizations may be used for analyzing changes to geometrical or structural properties of the at least one interpreted horizon.

Abstract: An exemplary method for filtering multi-component seismic data is provided. One or more characteristics of the seismic data corresponding to a relative manifestation of surface wave noise on the different components, such as polarization attributes, are identified. A time-frequency boundary in the seismic data is also identified in the time-frequency transform domain, the time-frequency boundary delineating portions of the seismic data estimated to contain surface wave noise (302). Finally, filtered seismic data are created (306) by removing portions of the seismic data that correspond to the identified characteristics of surface waves and that are within the time-frequency boundary (303).

Abstract: An exemplary embodiment of the present invention provides a method for interpolating seismic data. The method includes collecting seismic data of two or more types over a field (401), determining an approximation to one of the types of the seismic data (402), and performing a wave-field transformation on the approximation to form a transformed approximation (405), wherein the transformed approximation corresponds to another of the collected types of seismic data. The method may also include setting the transformed approximation to match the measured seismic data of the corresponding types at matching locations (408), performing a wave-field transformation on the transformed approximation to form an output approximation (412), and using the output approximation to obtain a data representation of a geological layer (416).

Abstract: A method for estimating velocity dispersion in seismic surface waves in massive 3-D data sets (401) that improves upon auto-picking of a curve along the peak or ridge of the magnitude of the beam-formed field (402). The seismic data are transformed to the frequency-slowness domain, where nonlinear constrained optimization is performed on the transformed data. The optimization matches a nonlinear mathematical parametric model (403) of a beam-formed field to that in the transformed data, adjusting the parameters each iteration to reduce mismatch (404). Dispersion curves are determined by the center of the beam in the optimized models (405). A preferred nonlinear parametric mathematical model is a Gaussian-shaped beam or a cosine-tapered boxcar beam.

Abstract: A computer-implemented method for pseudo acoustic quasi-P wave propagation which remain stable in anisotropic media with variable tilt and is not limited to weak anisotropic conditions. The method includes acquiring a seismic exploration volume for a subsurface region of interest, and determining a modeling geometry for the seismic exploration volume. The method further includes propagating at least one wavefield through the seismic exploration volume utilizing the modeling geometry and initial conditions and preventing the accumulation of energy along the axis of symmetry of the seismic exploration volume and ensuring positive stiffness coefficients in the stress-strain relations through the use of finite quasi-S wave velocities thereby producing a stable wavefield. The method includes utilizing the stable wavefield to generate subsurface images of the subsurface region of interest.

Abstract: Seismic image filtering machines, systems, program products, and computer implemented methods are provided to generate a filtered seismic image responsive to filtered seismic image data generated by attenuating coherent seismic noise from surface waves of an unfiltered wavefield constructed from unfiltered seismic image data through a single downward extrapolation of the unfiltered wavefield using a plurality of nonstationary convolution operators to perform localized filtering at each of a plurality of spatial locations of the unfiltered wavefield. Various embodiments, for example, can beneficially handle strong lateral velocity variations thus making various embodiments effective tools to remove complicated coherent seismic noise which is typically in the form of exponentially decaying evanescent waves.

Abstract: Translational data acquired by at least one translational survey sensor is received, and rotation data is received.

Abstract: An efficient and cost-effective technique is provided to perform modeling of a reservoir in a subterranean structure. A compartment model of fluid compartments in a reservoir is generated, and based on the compartment model and a geomechanical model of the subterranean structure, movement of a ground surface due to volumetric change of the compartments is calculated. Satellite measurements of the ground surface are received over time, where the received satellite measurements of the ground surface over time indicate movement of the ground surface. The movement of the ground surface indicated by the received satellite measurements is compared with the calculated movement, and based on the comparing, one or more properties of the geomechanical model are adjusted.

Abstract: Method of imaging seismic data recorded using a set of seismic receivers positioned to receive seismic responses from a subsurface formation upon activating a seismic source. The seismic responses are direction-sensitive responses. A virtual signal received by receiver k from the virtual source at the position of receiver m is determined by processing involving cross correlating at least part of the responses of a receiver m with at least part of the responses of a seismic receiver k. Part of direction-sensitive responses or part of the virtual signal that contains a component of the wave field at receiver m traveling in a first direction and part of the direction-sensitive responses or part of the virtual signal that contains a component of the wave field at the receiver k traveling in a second direction may be removed.

Abstract: A valve body has an elongated bore in communication with an inlet port and an outlet port. A valve element is movable within the bore between deactuated and actuated positions. A valve sensor generates a sensor signal indicative of an instantaneous parameter of the valve that changes between the deactuated and actuated positions. A logic unit receives the sensor signal and a pilot command signal that actuates the valve. A predetermined change in the pilot command signal causes the logic unit to determine a cycle parameter responsive to a time period between two predetermined events. At least the beginning or end of the time period corresponds to a predetermined value of the sensor signal. The individual determinations of the cycle parameter are accumulated to obtain an expected cycle parameter. The logic unit generates an indication signal when the cycle parameter exhibits a predetermined variance from the expected cycle parameter.

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

Abstract: Methods and systems for determining reservoir parameters of subterranean formations. A tool is configured or designed for deployment at at least one depth in a borehole traversing a subterranean formation. The tool comprises at least one sensor configured or designed for sensing rotational components of a seismic wavefield deployed in an array comprising at least one sensor configured or designed for sensing translational components of a seismic wavefield. A computer is in communication with the tool and a set of instructions executable by the computer that, when executed, process the seismic measurements and derive parameters relating to the formation based on the seismic measurements.

Abstract: A method for determining values of anisotropic model parameters of a Tilted Transversely Isotropic (TTI) Earth model, the method including obtaining an initial TTI earth model that substantially flattens common-imaging-point gathers and substantially ties seismic data to well data; inputting checkshot data and/or VSP data to determine updated values of Vp0 near the well locations; determining an incremental improvement ??; extrapolating the relative change ?? from near-well locations to the entire three dimensional TTI earth model; determining updated values of Vp0=Vp0 (1???); inputting near-to-mid-offset/angle and mid-to-far-offset/angle residual moveout information; and providing updated values of ? and ?.

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

Abstract: A method of imaging the Earth's subsurface using passive seismic interferometry tomography includes detecting seismic signals from within the Earth's subsurface over a time period using an array of seismic sensors, the seismic signals being generated by seismic events within the Earth's subsurface. The method further includes adaptively velocity filtering the detected signals. The method further includes cross-correlating the velocity filtered seismic signals to obtain a reflectivity series at a position of each of the seismic sensors.

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

Abstract: The invention relates to methods and computer-readable medium to determine seismic reflectivity attributes indicating the presence of hydrocarbons in earth. In several embodiments, the methods and computer-readable medium perform the steps of computing seismic reflectivity attributes includes inputting data representing reflected seismic waves and a volume of P-wave velocity, transforming the volume of P-wave velocity into a volume of bulk density, transforming the volume of P-wave velocity into a volume of S-wave velocity using amplitude information from the reflected seismic waves, and using the volume of S-wave velocity and the volume of P-wave velocity to compute the reflectivity attribute.

Abstract: 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.

Abstract: An electronic payment method for a retailer using an operator network and a financial organization. During a transaction two certificates are produced; one using an operator key and the other using a banking key. The first certificate is sent to the operator and the other certificate is securely placed under the control of the financial organization.

Abstract: 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.

Abstract: A well constrained horizontal variable height-velocity curve constructing method for seismic wave velocity field construction involves the steps of: a) calculating horizon velocity of each horizon by a sonic logging curve, and calculating the conversion horizon velocity of each horizon; b) drawing a circle to collect well points; c) calculating the characteristic parameter values of the height-velocity curve by the horizon velocity and the conversion horizon velocity of each well; d) calculating the characteristic parameter values by Kriging interpolation.

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