Abstract: Velocity tomography using time lags of wave equation migration is disclosed. Seismic tomography is a technique for imaging the subsurface of the Earth with seismic waves by generated a migration velocity model from a multitude of observations using combinations of source and receiver locations. The migration velocity model may be updated in order to reduce depth differences of reflection events (also called residual depth errors (RDE)). Direct measurement of RDE may be difficult in certain complex subsurface areas. In such areas, the RDE may be reconstructed based on time lags of wave equation migration and then used to update the migration velocity model. In particular, the RDE may be directly reconstructed from the time lags of wave equation migration, such as based on a direct relation between RDE and the time lags.

Abstract: Methods and devices for seismic exploration of an underground formation including an orthorhombic anisotropic medium or a tilted transverse isotropic medium are provided. Isotropic-type processing techniques use effective elastic parameter values calculated based on elastic parameter values, anisotropy parameter values and azimuth angle values for the orthorhombic anisotropic medium. For the tilted transverse isotropic medium, the effective elastic parameter values depend also on the tilt angle thereof.

Abstract: Methods and systems, including computer programs encoded on a computer storage medium can be used for an integrated methodology that can be used by a computing system to automate processes for generating, and updating (e.g., in real-time), subsurface reservoir models. The methodology and automated approaches employ technologies relating to machine learning and artificial intelligence (AI) to process seismic data and information relating to seismic facies.

Abstract: A multi-wavefield seismic detection method and system based on construction noise of a shield machine. Multi-wavefield seismic information such as a body wave and a surface wave formed during propagation of a seismic wave generated by excitation in a stratum is obtained by using noise information caused by the construction of a shield machine as a seismic source, a stratum velocity model along a tunnel is constructed through joint inversion, and reflection wave information or the like is used for migration imaging, to eventually implement relatively accurate detection of a geological condition in front of a tunnel face of shield construction.

Abstract: A dip angle-steering median filtering method based on a niche differential evolution algorithm, comprising the following steps: dividing a data to be processed into a series of overlapping time-space windows; obtaining an event energy curve in a time-space window and obtaining an event position according to a local maximum value of the event energy curve; obtaining event dip angles and coherence values of the event dip angles through the niche differential evolution algorithm at the event position; filtering the event dip angles according to the event dip angles and the coherence values of the event dip angles; and performing a median filtering sequentially along a filtering dip angle. The disclosure can simultaneously obtain all dip angles of intersecting events and a true three-dimensional feature enable the present disclosure to obtain a better filtering effect.

Abstract: Deconvolution-based processing of ultrasonic waveforms enables robust calculation of two-way travel time for an ultrasonic caliper, particularly in the presence of multiple, proximal reflectors (e.g., mud cake, formation, casing, cement, etc.).

Abstract: A method of obtaining a relative amplitude preserved seismic volume acquired in a time-domain for a subterranean region of interest and transforming it into a low-frequency monospectral amplitude volume. The method further determines a seismic attenuation volume from the relative amplitude preserved seismic volume acquired in the time-domain. Furthermore, the method generates a low-frequency monospectral amplitude map for a surface of interest by averaging the low-frequency monospectral amplitude volume over a depth-window around the surface of interest, and generates a seismic attenuation map for a surface of interest by averaging the seismic attenuation volume over a depth-window around the surface of interest. The method further determines an attribute map based on the seismic attenuation map and the low-frequency monospectral amplitude map for the surface of interest, and determines a presence of gas in the subterranean region of interest based on the attribute map.

Abstract: A method for modeling a subsurface volume includes receiving a plurality of ordered seismic images including representations of objects in the subsurface volume, generating flow fields based on a difference between individual images of the plurality of ordered seismic images, and identifying the objects in the seismic images based on the flow fields and the plurality of ordered seismic images.

Abstract: Techniques are described for generating seismic images based on pressure-shear (PS) wave information. Sensor data is generated by through seismic probing of an underground environment. The sensor data can include pressure (P) wave data. The sensor data is analyzed to determine PS wave data present in the sensor data. A CFP gathers spectrum is generated using the P wave velocity. An optimal curve through the CFP gathers spectrum is determined, and PS image(s) of the underground environment are generated by scanning along the optimal curve. The PS image(s) can be provided for presentation through interface(s). The generated PS wave images are correlated with P wave images, and can be plotted on the same coordinate system as P wave images.

Abstract: Various embodiments described herein provide methods of hydrocarbon management and associated systems and/or computer readable media including executable instructions. Such methods (and by extension their associated systems and/or computer readable media for implementing such methods) may include obtaining geophysical data (e.g., seismic or other geophysical data) from a prospective subsurface formation (that is, a potential formation or other subsurface region of interest for any of various reasons, but in particular due to potential for production of hydrocarbons) and using a trained machine learning (ML) system for direct hydrocarbon indicators (DHI) analysis of the obtained geophysical data. Hydrocarbon management decisions may be guided by the DHI analysis.

Abstract: A seismic exploration method includes performing a true amplitude PSDM based on an initial velocity model of a subsurface formation to obtain a reflectivity model, and then a Born modeling using the reflectivity model to generate synthetic data. An image-based reflection full waveform inversion is applied to a cost function of differences between seismic data acquired over the subsurface formation and the synthetic data to update the initial velocity model. The updated velocity model enables exploring the presence of and/or assisting in the extraction of natural resources from the subsurface formation.

Abstract: A method of processing a three-dimensional (3D) seismic dataset includes: producing a relative amplitude preserved (RAP) processed seismic volume that includes a reservoir from the 3D seismic dataset; decomposing the RAP processed seismic volume into a first iso-frequency volume; generating a first overburden sediment interval map and a first reservoir interval zone map for the first iso-frequency volume; generating and outputting a first ratio map for the first iso-frequency volume by dividing the first overburden sediment interval map by the first reservoir interval zone map; and characterizing a fluid content of the reservoir based on the first ratio map.

Abstract: A computer system receives a post-stack time-domain image having a first spectrum and representing one or more subsurface structures. The computer system reconstructs an increased-frequency version of the post-stack time-domain image using L0-constrained inversion and a least-squares mismatch ratio. The increased-frequency version of the post-stack time-domain image includes structural artifacts. The computer system removes the structural artifacts from the increased-frequency version of the post-stack time-domain image using singular value decomposition. The computer system combines the increased-frequency version of the post-stack time-domain image with the post-stack time-domain image using a weighting function. The computer system generates a combined version of the increased-frequency version of the post-stack time-domain image and the post-stack time-domain image. The combined version represents the one or more subsurface structures and has a second spectrum broader than the first spectrum.

Abstract: A system includes a processor and a memory. The memory includes instructions that are executable by the processor to access a plurality of seismic images of a subterranean formation in a first geological area. The instructions are also executable to generate a plurality of fault estimates from each of the plurality of seismic images. Further, the instructions are executable to generate a processed seismic image of the first geological area by normalizing and merging the plurality of seismic images and the plurality of fault estimates. Additionally, the instructions are executable to generate a statistical fault uncertainty volume of the first geological area using the processed seismic image. Furthermore, the instructions are executable to control a drilling operation in the first geological area using the statistical fault uncertainty volume of the first geological area.

Abstract: A method for characterizing a hydraulic fracture treatment both operationally and in a subsurface formation includes inducing a pressure change in a well drilled through the subsurface formation. At least one of pressure and a time derivative of pressure is measured in the well for a selected length of time. At least one physical parameter of at least one fracture is determined using the measured pressure and/or the time derivative of pressure. A method of evaluating hydraulic fracturing treatment and operations by monitoring resonant structures present while fracturing. A method for characterizing hydraulic fracturing rate uses microseismic event count measured through the wellbore and its real-time implementation.

Abstract: Systems and methods are disclosed that include generating reservoir property profiles corresponding to reservoir properties for pseudo wells based on reservoir data, generating seismic attributes for the pseudo wells, and training a machine learning model by comparing the reservoir property profiles against the seismic attributes. In this manner, the machine learning model may be used to predict reservoir properties for use with seismic exploration above a region of a subsurface that contains structural or stratigraphic features conducive to a presence, migration, or accumulation of hydrocarbons.

Abstract: This invention relates to a method for determining a location of karst caves in a geological model. The method comprising for each current point of a set of points of a closed space of the model, determining a distance value; receiving an average value; and for each current point of the set of points of the closed space, determining a presence of caves for the current point. The determination at the presence of caves depends at least on the received average value and on the distance value determined for the current point. A collapse procedure can also be implemented as described in the description.

Abstract: The present disclosure generally relates to an interface system and method of interfacing to generate data compatible with an external system in an oil and gas asset supply chain, and in particular to an interface and interface method for generating secure and verifiable data to prevent tampering, injection of unwanted data resulting from an unauthorized access along a supply chain. An interface generates and transforms data in an oil and gas supply chain for compatibility with external systems. Collected data is captured by an industrial control system sensor or data collector, which is transferred in a secure intermediary hardware platform to interface with a software component. The collected data is then modified using a business rules engine to create enhanced data and events created from the enhanced data.

Abstract: A method of estimating formation parameters in a directional drilling process by acquiring electromagnetic logging while drilling (LWD) measurements over a non-uniform forward modeling grid and inverting, using a pixel-based inversion method, the LWD measurements over a uniform inversion grid. The inversion algorithm may be applied using a sliding window scheme that allows the formation parameters to be estimated independently and in parallel across a plurality of overlapping windows which span the entirety of the inversion grid.

Abstract: A method is described for improving subsalt seismic imaging using wavefield redatuming. The method redatums the source wavefield and receiver wavefield to the salt surface. It cross-correlates the redatumed wavefields and uses the time cross-correlations to update the salt surface. The method may be executed by a computer system.

Abstract: A method, including performing, with a computer, up/down separation of geophysical data, which produces an approximate up-going wavefield and an approximate down-going wavefield; creating an areal source based at least in part on the down-going wavefield; and performing, with a computer, a full wavefield inversion process with the areal source, and an objective function measuring a misfit between modeled up-going wavefields and recorded up-going wavefields, wherein the full wavefield inversion process generates a final subsurface physical property model.

Abstract: A method for improving a redundancy and an uptime in a SCADA network for controlling a well operation includes executing control systems for the well operation in identical virtual simulated environments on at least two servers, storing all data for the control systems in a designated redundant cluster storage system, and setting-up the at least two servers with a load balancing.

Abstract: A method for processing broadband single-sensor single-source land seismic data includes receiving seismic traces, the seismic traces generated using at least one source and at least one receiver; converting the seismic traces from particle motion measured by the at least one receiver to particle motion represented by the at least one source by applying a deterministic differential filtering operation; applying a deterministic inverse-Q filtering operation on the converted seismic traces; processing the inverse-Q filtered seismic traces using a set of surface-consistent filter and attribute corrections; and generating a seismic image based on the processed seismic traces.

Abstract: A method for modeling and analyzing the impact of different seismic surveying and imaging techniques on a subterranean formation uses a black hole boundary condition around a particular region in the formation where at least one of the physical characteristics is unclear and may distort the seismic modeling results. The black hole boundary conditions will eliminate any energy wave that enters, exit or reflect off the region so as to avoid any image distortion caused by this region. The resulted image data is compared with the image data obtained without using the black hole boundary conditions to determine the impact of this region, and proper correction can be made to more precisely and accurately model the formation.

Abstract: The presently disclosed seismic acquisition technique employs a receiver array and a processing methodology that are designed to attenuate the naturally occurring seismic background noise recorded along with the seismic data during the acquisition. The approach leverages the knowledge that naturally occurring seismic background noise moves with a slower phase velocity than the seismic signals used for imaging and inversion and, in some embodiments, may arrive from particular preferred directions. The disclosed technique comprises two steps: 1) determining from the naturally occurring seismic background noise in the preliminary seismic data a range of phase velocities and amplitudes that contain primarily noise and the degree to which that noise needs to be attenuated, and 2) designing an acquisition and processing method to attenuate that noise relative to the desired signal.

Abstract: Disclosed herein is a system and method for building a velocity model for a geographical area of interest (GAI). The system and method comprise determining a ray based tomography velocity image of said GAI using acquired data, determining a high resolution velocity guide (HRVG) image of said GAI, scaling said determined HRVG of said GAI, adding the scaled HRVG to the ray based tomography velocity image to determine an updated ray based tomography velocity image, and determining whether said updated ray based tomography velocity image has experienced convergence by determining whether a cost function of said ray based tomography velocity image does not improve compared to a previously determined cost function value of said ray based tomography velocity image.

Abstract: A method of analyzing a 3D geological structure using a structure index. The method includes the steps of estimating physical property values on common coordinates to calculate two or more physical property models on the same 3D grid (L×M×N); normalizing the physical property models, thus obtaining normalized physical property models which are then represented in a scatter plot of physical properties; converting distribution positions of the normalized physical property models on the scatter plot of physical properties into type angle (TA) and into type intensity (TI); determining a minimum of TI values, which classifies two or more classes on a scatter plot of the TA and TI values, to be a threshold; and analyzing the 3D geological structure based on a local extreme point and/or points in the scatter plot for the TA and TI using the threshold.

Abstract: A technique for determining a set of surface profiles in a multilayer stack during a fabrication process may be determined using a model of this fabrication process, a geometry of the multilayer stack (such as a pre-defined geometry of the multilayer stack) and a surface profile in the multilayer stack (such as a measured surface profile of the top surface or a bottom surface of the multilayer stack). For example, the model of the fabrication process may be based on a generalized Eikonal equation. In conjunction with deposition rates and/or physical properties of the layers in the multilayer stack, deposition or growth of the multilayer stack may be simulated. Based on the determined set of surface profiles, an acceptance condition of the multilayer stack (such as a multilayer stack in a photo-mask for use in extreme ultra-violet photolithography) may be determined and/or a remedial action may be recommended.

Abstract: Methods and apparatus for noise removal from seismic data. In one embodiment, a seismic data set comprising a plurality of traces is received, and noise metrics for the seismic data set are computed using a set of time and depth windows. The seismic data set is scanned to determine a first set of groups. Each group in the first set comprises at least a first minimum number of neighboring traces for which at least one of the noise metrics is outside a predefined specification. Noise attenuation is applied to the traces in the first set of groups. Other embodiments, aspects, and features are also disclosed.

Abstract: A technique dynamically maintains and enforces relative policies for a prefix in a computer network. According to the novel technique, a node (e.g., an optimized edge router, OER) monitors performance characteristics for a particular prefix policy over a current path, and maintains a long-term average (LTA) value and a short-term average (STA) value of the performance characteristic. In the event the STA is worse than the LTA by a configurable amount, the prefix is considered “out-of-policy” (OOP) for that policy, and a new path may be selected accordingly. Otherwise, the prefix is considered “in-policy,” and the current path is upheld. Notably, a threshold may be manually configured to account for slow performance deterioration or “spikes,” such that if the performance characteristic (or STA) surpasses the threshold, the prefix is considered OOP.

Abstract: The illumination/imaging of a theorized target horizon that is below a theorized velocity contrast horizon where the velocity contrast horizon may represent the bottom of a salt dome by assessing the path of seismic energy for critical angle reflection/refraction and tabulates the successful paths and unsuccessful paths. For some subsurface locations, seismic energy will not reach the surface above the velocity contrast due to the shapes of the velocity contrast horizon and target horizon and the velocity model through which the studied waves propagate. Displays may be prepared and used for understanding illumination/imaging of the geology for drilling, reacquisition, and reprocessing to elicit information about subsurface geology that may have been overlooked or ignored. Future surveys avoid expensive surveying which cannot obtain useful seismic data as determined by the velocity contrast for the target locations due to the shapes of the horizons and the velocity model.

Abstract: A method, apparatus and system for, in a computing system, perturbing an initial three-dimensional (3D) geological model using a 3D vector field. A coherent 3D vector field including 3D vectors may be generated where each 3D vector of the 3D vector field is associated with a node of the initial 3D geological model and has a magnitude within a range of uncertainty of the node of the initial 3D geological model associated therewith. The coherent 3D vector field may be applied to the initial 3D geological model associated therewith to generate an perturbed 3D model. The perturbed 3D model may differ from the initial 3D geological model by a displacement defined by the 3D vector field associated with nodes having uncertain values. The perturbed 3D model may be displayed.

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: A computer-implemented process includes: performing a first foil waveform inversion on an initial subsurface attribute model using low frequency, known source-signature data and low frequency humming seismic data to generate a first updated subsurface attribute model; and performing a second full waveform inversion on the first updated subsurface attribute model using low-frequency, narrowband sweeping known source-signature data and low-frequency, swept seismic data to generate a second updated subsurface attribute model. The process may be performed by a suitably programmed computing apparatus, the program residing on some form of non-transitory program storage medium.

Abstract: A method for determining properties of a formation comprises disposing at least one acoustic logging tool in a well and moving the logging tool along the well. An acoustic logging is performed during movement of the acoustic logging tool together with simultaneous thermal treatment of the formation. A temperature of a formation zone being thermally treated is measured as well as attenuation and velocity of the Stoneley waves excited by the acoustic logging tool. Based on the obtained dependencies of measured parameters as functions of the formation zone temperature formation relative phase permeabilities, formation fluid viscosity and viscous flow activation energy are determined.

Abstract: Techniques for estimating velocity ahead of a drill bit include generating seismic waves at a surface from at least two different source positions in the vicinity of a borehole, receiving seismic waves reflected from a reflector ahead of the drill bit at one or more locations in the borehole, determining travel times of the seismic waves received at the one or more locations in the borehole, and inverting the travel times to determine a velocity of a formation ahead of the drill bit. One embodiment includes transforming the velocity into pore pressure of the formation.

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: Methods for fracture characterization of unconventional formations are provided. Synthetic seismic fracture responses can be generated based on the derived fracture parameters. The synthetic seismic fracture responses may then be used to derive optimum seismic data acquisition geometry for fracture characterization. These methods of determining the seismic data acquisition geometry are advantageous over conventional methods in that these methods are more reliable and cheaper than existing empirical methods, particularly as applied to fractured unconventional formations. Moreover, these methods allow fracture parameters to be derived from limited but common well log data. Certain embodiments additionally contemplate determining the presence of gas filled fractures. These characterizations and evaluations of unconventional formations are useful for, among other things, determining optimal producing intervals and optimal drilling locations. These methods can eliminate the use of costly image logs and core data.

Abstract: Apparatuses and methods for collecting and analyzing seismic data (D) include a frequency dependent noise factor (?2) for stabilizing a transformation matrix (S). The noise factor (?2) is a function of a number of nonzero eigenvalues of the transformation matrix (S).

Abstract: Method for acquiring, at reduced acquisition cost, seismic data using simultaneous, field-encoded sources in the field (702), and then constructing pseudo source-records (703) that better meet the requirements for using additional simultaneous computer-encoded sourcing for computer simulations or forward modeling (706) as part of (707) iterative FWI (Full Wavefield Inversion) or RTM (Reverse Time Migration), with additional reduction in computational costs. By better meeting the requirements of simultaneous sourcing for FWI or RTM (701), artifacts and crosstalk are reduced in the output. The method can be used for marine streamer acquisition and other non-fixed spread geometries to acquire both positive and negative offsets and to mitigate the “missing data” problem for simultaneous-source FWI. It can also be used for land data to overcome issues with moving spreads and long continuous records.

Abstract: Method for using the full wavefield (primaries, internal multiples and free-surface multiples) in inversion of marine seismic data, including both pressure and vertical velocity data (21), to infer a subsurface model of acoustic velocity or other physical property. The marine seismic data are separated (22) into up-going (23) and down-going (24) wavefields, and both wavefields are inverted in a joint manner, in which the final model is impacted by both wavefields. This may be achieved by inverting both wavefields simultaneously (25), or one after the other, i.e. in a cascaded approach (35?37, or 45?47), for the subsurface properties (26, 38, 48).

Abstract: A method of subsurface imaging is disclosed, the method involving using input data relating to the geometry of a fracture in a subsurface medium, mechanical properties of the medium and in-situ stress states in the medium, to model the behavior of the fracture and obtain predicted information relating to deformation of the fracture. The predicted information is then used to constrain the interpretation of measured microseismic data caused by movement of the fracture to determine characteristics of the movement and/or failure of the fracture.

Abstract: A measured pressure field, a measured vertical velocity field, and two measured orthogonal horizontal velocity fields are obtained. A programmable computer is used to perform the following. A scaling factor is determined from water acoustic impedance, the measured pressure field, and the horizontal velocity fields. One of the measured pressure field and measured vertical velocity field is combined with one of the measured vertical velocity field scaled by the scaling factor and the measured pressure field scaled by the scaling factor, generating one of up-going and down-going pressure and velocity wavefields.

Abstract: Simulators and methods for simulating an acoustic field of an acoustic waveguide are provided. A sound speed profile of the acoustic waveguide is generated, where the acoustic waveguide has a region of a first fluid within a second fluid, and the first fluid has a different acoustic index of refraction than the second fluid. The sound speed profile and predetermined parameters of a sound source and a receiver are applied to a parabolic equation (PE) model of sound propagation in the acoustic waveguide. The acoustic field of the acoustic waveguide is determined from the PE model. The acoustic field includes an interference pattern from interference between an acoustic signal of the acoustic source and at least one signal refracted by the region of the second fluid.

Abstract: A well constrained transverse variable height-velocity curve constructing method for seismic wave velocity field construction involves the steps of: a) calculating interval velocity of each stratum 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 interval velocity and the conversion interval velocity of each well; d) calculating the characteristic parameter values by Kriging interpolation.

Abstract: Embodiments of locating seismic events are disclosed. In one embodiment, a single difference seismic locator and a reverse double difference seismic locator are combined into a combined system of equations, and the combined system of equations is solved to determine a location of the seismic event in substantially real time relative to the seismic event. The combined system of equations may be weighted such that the determined location of the seismic event is partially influenced by the single difference seismic locator and partially influenced by the reverse double difference seismic locator.

Abstract: Methods for identifying hydrocarbon plays include applying predictive models to sediment fill volume(s) to provide play-element volume(s) representing at least one play element. Each play-element volume represents at least 1) qualities of the at least one play element and 2) a probability that the at least one play element satisfies determined criteria for each of a plurality of locations within a basin. The methods further include analyzing the play-element volume(s) to define play-concept volume(s) representing hydrocarbon play(s). Each of a plurality of locations within the play-concept volume(s) is attributed with: 1) an identification of each play element associated with the location, 2) the qualities of each play element, 3) the probability for each play element that it satisfies determined criteria, and 4) a composite likelihood that the location represents a hydrocarbon play. At least one of the volumes may be used to identify hydrocarbon play(s).

Abstract: A method of processing seismic data including measurement data and their gradients to obtain gradients of move-out corrected data, comprising deriving gradients of the measurement data, deriving a first term comprising applying a move-out correction function to the measurement data; deriving a second term by applying the move-out correction function to the gradients and deriving gradients of move-out corrected data by adding the first term and the second term. The gradients of move-out corrected data are used to process physical properties of the earth's interior. The method may be used prior to any data processing algorithm which uses measurement gradient data in which move-out correction is applied prior to the algorithm, either because the algorithm makes a zero offset assumption or because it is beneficial for the algorithm to operate on move-out corrected data to reduce aliasing.

Abstract: Methods and related systems are described for measuring and analyzing refracted acoustic energy. A plurality of receivers mounted are on a downhole tool, and are arranged and adapted to receive refracted acoustic energy from a downhole formation. Measurements of refracted acoustic energy is analyzed such that information relating to an azimuthal direction relative to the downhole tool of an interface within the downhole formation can be estimated. The receivers can be mounted on a drill collar as part of a LWD tool and steering of the drilling trajectory can be based in part on the estimated formation information.

Abstract: Methods and computing systems for processing seismic data are disclosed. In one embodiment, a method for processing seismic data comprises receiving seismic data that includes active data corresponding to an active shot from a seismic source. The processing includes processing at least a portion of the active data using a passive data processing technique.