A system can be provided for applying a dynamic filter to a velocity model for converting the domain of seismic data. The system can receive a velocity model for a geological area of interest. The system can apply a dynamic filter to the velocity model for smoothing an anomaly included in the velocity model. The system can apply the velocity model with the smoothed anomaly to seismic data associated with the geological area of interest for converting the domain of the seismic data.

There is a method for correcting seismic wave propagation paths through the earth. The method includes determining a first fixed shooting sequence for a first bandlimited seismic source; determining a second shooting sequence for a second bandlimited seismic source, wherein the second shooting sequence includes second shooting positions that correspond to second energy emissions, and the second energy emissions differ from the first energy emissions in at least one of an emission time, phase and amplitude; receiving raw seismic data recorded with seismic receivers and generated as a result of the first and second energy emissions, wherein the raw seismic data is indicative of seismic wave paths from the first and second bandlimited seismic sources to the seismic receivers; separating the raw seismic data into a first bandlimited set corresponding to the first bandlimited seismic source and a second bandlimited set corresponding to the second bandlimited seismic source; and correcting the seismic wave paths, from the first and second bandlimited seismic sources to the seismic receivers, based on at least one of the first and second bandlimited sets.

There is a method for correcting seismic wave propagation paths through the earth. The method includes determining a first fixed shooting sequence for a first bandlimited seismic source; determining a second shooting sequence for a second bandlimited seismic source, wherein the second shooting sequence includes second shooting positions that correspond to second energy emissions, and the second energy emissions differ from the first energy emissions in at least one of an emission time, phase and amplitude; receiving raw seismic data recorded with seismic receivers and generated as a result of the first and second energy emissions, wherein the raw seismic data is indicative of seismic wave paths from the first and second bandlimited seismic sources to the seismic receivers; separating the raw seismic data into a first bandlimited set corresponding to the first bandlimited seismic source and a second bandlimited set corresponding to the second bandlimited seismic source; and correcting the seismic wave paths, from the first and second bandlimited seismic sources to the seismic receivers, based on at least one of the first and second bandlimited sets.

A method for classifying a microseismic event, including: analyzing microseismic event files through a combination of two fault tolerant machine learning pipelines, an acoustic machine learning pipeline and a visual machine learning pipeline; and generating a classification prediction for the microseismic event files by combining predictions from the acoustic machine learning pipeline and the visual machine learning pipeline.

System and methods for automated seismic processing are provided. Historical seismic project data associated with one or more historical seismic projects is obtained from a data store. The historical seismic project data is transformed into seismic workflow model data. At least one seismic workflow model is generated using the seismic workflow model data. Responsive to receiving seismic data for a new seismic project, an optimized workflow for processing the received seismic data is determined based on the at least one generated seismic workflow model. Geophysical parameters for processing the seismic data with the optimized workflow are selected. The seismic data for the new seismic project is processed using the optimized workflow and the selected geophysical parameters.

Systems, methods, and apparatuses for generating a subsurface image using diffraction energy information are disclosed. The systems, methods, and apparatuses may include converting a shot gather into one or more plane-wave gather using a Radon transform. The plane-wave gathers may be extrapolated into source-side wavefields and receiver-side wavefields and further generate a pseudo dip-angle gather. The diffraction energy information may be extracted from the pseudo dip-angle gather, and an image containing subsurface features may be generated from the extracted diffraction energy information. The receiver-side wavefields may be decomposed using a recursive Radon transform.

A fully automated method for correcting errors in one interpretation (13) of seismic data based on comparison to at least one other interpretation (14) of the same subsurface region. The errors may occur in any feature of the seismic data volume, for example a horizon, surface, fault, polyline, fault stick, or geo-body. In some embodiments of the invention, an error may be a hole in a horizon (53), and the whole is patched by a piece of a horizon in another interpretation (55). In an alternative embodiment of the invention, a single interpretation may be used to repair itself, for example by identifying similarly shaped, adjacent horizons (67), and merging them (68).

The present invention is a method to determine an azimuthal orientation of a borehole seismometer sensor performed by a computing device using a control server having a database and an arithmetic function, the computing device performing a method to determine the azimuthal orientation of a borehole seismometer sensor using long-period surface waves in microseisms, including step S100 in which a data collection unit 100 collects continuous waveform data recorded by a borehole seismometer and a reference seismometer; step S200 in which a frequency band setting unit 200 sets a frequency band to be analyzed in the collected continuous waveform data; step S300 in which a filtering unit 300 performs bandpass filtering on the frequency band to be analyzed; step S400 in which a waveform dividing unit 400 divides seismic waveform into waveform segments with preset time units; step S500 in which a phase shift unit 500 shifts the phase of the divided vertical component waveforms by 90°; step S600 in which a waveform calculation unit 600 combines the divided N′ and E′ component seismic waveforms to calculate horizontal components for rotation angles waveform between 0 and 360° from the N′ orientation; step S700 in which a correlation calculation unit 700 calculates a correlation coefficient between the horizontal and vertical component waveforms; step S800 in which a Rayleigh wave orientation determination unit 800 repeats steps S500 to S700 for each divided time domain; step S900 in which an orientation comparison unit 900 performs steps S400 to S800, respectively, with respect to the borehole seismometer data for which the sensor orientation is to be determined and the reference seismometer data for which the sensor orientation is already known; and step S1000 in which a result calculation unit 1000 averages 0 determined for each time period to calculate a final result.

An efficient adaptive seismic data flow lossless compression and decompression method, which aims at solving the problem that data occupies the storage space and affects the transmission efficiency and is used for efficiently compressing geophysical instrument data, particularly seismic data after 24-bit analog-to-digital conversion. In the method, a data flow is compressed in a lossless mode in real time, and sampling data is adaptively compressed into 1 byte or 2 bytes or 3 bytes from original 24 bits and 3 bytes in a coding manner. Besides the foregoing data ranges, other integers that can be expressed by other 24-bit integer data with symbols are required to be expressed by 4 bytes after being operated through a compression algorithm. The method has the advantages of saving a large amount of storage space and remarkably increasing the data transmission efficiency.

The present invention relates to a one-way wave equation prestack depth migration method using an elastic generalized-screen (EGS) wave propagator capable of efficiently expressing the movement of an elastic wave passing through a mutual mode conversion between a P-wave and an S-wave while propagating boundary surfaces of an underground medium, by expanding, to an elastic wave equation, a conventional scalar generalized-screen (SGS) technique capable of quickly calculating the propagation of a wave in a medium in which there is a horizontal speed change, and according to the present invention, provided is a prestack EGS migration method for seismic wave multi-component data, which: can calculate a wave field with higher accuracy in a medium having a complex structure by expanding up to a second term of a Taylor series expansion of a vertical slowness term of a propagator; includes a mode separation operator in the propagator so as to directly use a shot gather as a migration input, without the need to separate multi-component data into a P-wave and an S-wave, enabling P-wave and S-wave image sections to be generated; and is configured to improve the quality of an S-wave migration image by correcting a polarity conversion in a wave number-frequency domain prior to S-wave imaging.