A method for generating a seismic image representing a subsurface includes receiving seismic data for the subsurface formation, including receiver wavelet data and source wavelet data. Source wavefield data are generated based on a forward modeling of the source wavelet data. Receiver wavefield data are generated that compensate for distortions in the seismic data by: applying a dispersion-only model to the receiver wavelet data to generate a first reconstructed back-propagated receiver wavefield portion, applying a dissipation-only model to the receiver wavelet data to generate a second reconstructed back-propagated receiver wavefield portion, and combining the first back-propagated receiver wavefield portion and the second back-propagated receiver wavefield portion into the receiver wavefield data. The method includes applying an imaging condition to the receiver wavefield data and the source wavefield data and generating, based on applying the imaging condition, visco-acoustic reverse time migration (VARTM) result data.

Methods, systems, and computer readable media for gridding of subsurface salt structures include determining a predetermined area lacks three dimensional seismic coverage, generating a two dimensional seismic top salt interpretation for the predetermined area, generating a bathymetry elevation of the predetermined area, determining that at least one two dimensional seismic line intersects a bathymetric feature of interest, and determining a correlation coefficient between the two dimensional seismic top salt interpretation and the bathymetry elevation. The method may further include determining the correlation coefficient is greater than a predetermined threshold value, and applying the bathymetry elevation as an additional control for gridding top of the subsurface salt structure. The step of gridding the top of the subsurface salt structure may further include applying at least one of kriging with external drift (KED), polygon-based approaches, regression-kriging, and other geostatistical methods.

The embodiments of the present application disclose a method for acquiring a converted wave, an electronic device, and a readable storage medium, wherein the method for acquiring a converted wave comprises: acquiring a relational expression between a P-wave reflection coefficient and an incident angle by Zoeppritz equation; simplifying the relational expression between the P-wave reflection coefficient and the incident angle; calculating a derivative for the simplified relational expression between the P-wave reflection coefficient and the incident angle, to obtain an expression of a wave to be converted; correcting parameters in the expression of the wave to be converted to obtain a converted wave.

The embodiments of the present application disclose a method for acquiring a converted wave, an electronic device, and a readable storage medium, wherein the method for acquiring a converted wave comprises: acquiring a relational expression between a P-wave reflection coefficient and an incident angle by Zoeppritz equation; simplifying the relational expression between the P-wave reflection coefficient and the incident angle; calculating a derivative for the simplified relational expression between the P-wave reflection coefficient and the incident angle, to obtain an expression of a wave to be converted; correcting parameters in the expression of the wave to be converted to obtain a converted wave.

Systems and methods that include receiving reservoir data of a hydrocarbon reservoir, receive an indication related to selection of a wavefield propagator, application of the wavefield propagator utilizing Fourier Finite Transforms and Finite Differences to model a wavefield associated with a Tilted Orthorhombic media representative of a region of a subsurface comprising the hydrocarbon reservoir, and processing the reservoir data in conjunction the wavefield propagator to generate an output for use with seismic exploration above a region of a subsurface comprising the hydrocarbon reservoir and containing structural or stratigraphic features conducive to a presence, migration, or accumulation of hydrocarbons.

A process for seismic imaging of a subterranean geological formation includes generating a source wavefield from seismic data representing a subterranean formation. The process includes generating a receiver wavefield from the seismic data representing the subterranean formation. The process includes decomposing the source wavefield to extract a source depth component and decomposing the receiver wavefield to extract a receiver depth component. The process includes applying a transform to each of the source depth component and the receiver depth component. The process includes combining the source depth component and the receiver depth component to generate an imaging condition. The process includes extracting a low-frequency term from the imaging condition to generate a wave-path tracking data, generating a wave path from the wave-path tracking data, and rendering a seismic image of at least a portion of the subterranean geological formation from the generated wave path.

An apparatus, method, and non-transitory computer readable medium that can mitigate wireless channel impairments in seismic data transmission using deep neural networks is disclosed. The apparatus includes a receiving circuitry to receive seismic data and a processing circuitry. The processing circuitry is configured to apply a blind system identification process to the seismic data to estimate a channel impulse response of the seismic data, apply an optimum equalization process to obtain estimated seismic data based on the channel impulse response, process the estimated seismic data to generate processed seismic data, classify the processed seismic data into a first group of seismic data each of which has a signal-to-noise ratio (SNR) less than an SNR threshold and a second group of seismic data each of which has an SNR no less than the SNR threshold, and enhance the SNR of each of the first group of seismic signals.

A method is disclosed that includes: obtaining a seismic data volume for a subterranean region of interest; transforming, by a computer processor using a non-stationary series analysis, the seismic data volume into a seismic spectral volume where the seismic spectral volume includes a seismic spectrum for each of a plurality of voxels; and determining a seismic attribute volume composed of a seismic attribute for each of the plurality of voxels. The seismic attribute for a voxel of the plurality of voxels is based, at least in part, on an integral of the seismic spectrum for the voxel over a range bounded by a first frequency and a second frequency. The method further includes determining a presence of hydrocarbon in the subterranean region of interest based on the seismic attribute volume. A system for performing the method is also disclosed and described.

Systems and methods include a computer-implemented method includes concurrently outputting, by a computing device to a display of the computing device, a graphical time-domain interpretation of seismic data, a graphical velocity model related to the seismic data, and a graphical depth-domain interpretation of the seismic data. The method may further include identifying, by the computing device, a first alteration to one of the time-domain interpretation, the velocity model, and the depth-domain interpretation. The method may further include identifying, by the computing device based on the first alteration, a second alteration to another of the time-domain interpretation, the velocity model, and the depth-domain interpretation. The method may further include updating, by the computing device based on the first alteration and the second alteration, at least two of the graphical time-domain interpretation, the graphical velocity model, and the graphical depth-domain interpretation. Other embodiments may be described or claimed.

Systems and methods for quantitative seismic integrated modelling (QSIM) are disclosed for integrating the one, two and three-dimensional (1D, 2D, 3D) data from different geoscience domains within a framework in order to produce hi-resolution geocellular models that simulate realistic sub-surface reservoir properties. The QSIM systems and methods accurately leverage the seismically derived reservoir rock properties, integrating the geophysical, geological and engineering information through an optimum rock physics models and takes in consideration all the empirically constrained templates to correct, validate and quality check all the input data.