Method and apparatus for suppressing mechanicals in seismic data

Abstract

This specification provides a method and apparatus for suppressing mechanical interference in seismic data. The method includes: acquiring target seismic data for a target area; wherein the target seismic data packet contains mechanical interference; performing a shearing transformation on the target seismic data to obtain multiple first data components; processing the multiple first data components according to a preset first processing rule; and suppressing first-type mechanical interference by performing an inverse shearing transformation on the processed multiple first data components; suppressing second-type mechanical interference by performing compressed sensing reconstruction on the first-suppressed target seismic data according to a preset second processing rule; and stopping the suppression process according to a preset detection rule, and determining the current second-suppressed target seismic data as the target seismic data after suppressing mechanical interference. This method effectively suppresses complex mechanical interference while avoiding damage to valid seismic signals.

Description

Technical Field

[0001] This manual belongs to the field of oil and gas exploration technology, and in particular relates to methods and devices for suppressing mechanical interference with seismic data. Background Technology

[0002] In oil and gas exploration, it is often necessary to collect seismic data of the area of ​​interest in order to analyze and predict the distribution of oil and gas in the region. However, the directly acquired seismic data usually contains complex mechanical interferences. For example, there are various linear interferences generated by surrounding factories, hammers, drilling rigs, and other interference sources.

[0003] These complex mechanical interferences vary in their formation mechanisms, propagation modes, and spectral characteristics, significantly impacting the signal-to-noise ratio of seismic data. This results in lower accuracy, larger errors, and even complete unusability of the acquired seismic data. Furthermore, the interference signals generated by these complex mechanical interferences have a high degree of overlap with the valid seismic signals in the seismic data. This makes it difficult to effectively separate and suppress such interference from seismic data using existing methods. Moreover, suppressing these mechanical interferences using existing methods can easily damage the valid seismic signals in the seismic data.

[0004] There is currently no effective solution to the above problems. Summary of the Invention

[0005] This specification provides a method and apparatus for suppressing mechanical interference in seismic data. By combining shear transformation, inverse shear transformation, and compressed sensing reconstruction on the target seismic data according to corresponding processing rules, it is possible to effectively suppress complex mechanical interference in the target seismic data, which contains at least type I and type II mechanical interference. At the same time, it is also possible to avoid damaging the effective seismic signals in the target seismic data, and obtain target seismic data with high accuracy and relatively complete mechanical interference suppression.

[0006] This specification provides a method for suppressing mechanical interference in seismic data, including:

[0007] Acquire target seismic data about a target area; wherein the target seismic data contains mechanical interference, and the mechanical interference includes at least type I mechanical interference and type II mechanical interference;

[0008] The target seismic data is sheared to obtain multiple first data components; wherein the multiple first data components correspond to different frequency scales and dip directions.

[0009] process the plurality of first data components according to a preset first processing rule; and suppress the first type of mechanical interference by performing inverse shear transformation on the plurality of processed first data components to obtain first suppressed target seismic data;

[0010] suppress the second type of mechanical interference by performing compressive sensing reconstruction on the first suppressed target seismic data according to a preset second processing rule to obtain second suppressed target seismic data;

[0011] detect whether the second suppressed target seismic data meets a preset requirement according to a preset detection rule;

[0012] determine the second suppressed target seismic data as the target seismic data after suppressing mechanical interference in a case where it is determined that the second suppressed target seismic data meets the preset requirement.

[0013] In one embodiment, the first type of mechanical interference includes linear interference with a difference in dip angle from effective seismic signals in the target seismic data; and the second type of mechanical interference includes linear interference with the same dip angle as the effective seismic signals in the target seismic data but a difference in frequency.

[0014] In one embodiment, processing the plurality of first data components according to a preset first processing rule includes:

[0015] obtaining seismic velocities of each of the plurality of first data components according to the preset first processing rule;

[0016] selecting, from the plurality of first data components, a first data component with a difference in dip angle and / or frequency according to the seismic velocities, and marking the first data component as a difference first data component;

[0017] setting a shear transformation coefficient of the difference first data component in the plurality of first data components to 0; and performing inverse shear transformation on the plurality of first data components after the setting.

[0018] In one embodiment, suppressing the second type of mechanical interference by performing compressive sensing reconstruction on the first suppressed target seismic data according to a preset second processing rule includes:

[0019] splitting the first suppressed target seismic data into a plurality of second data components according to the preset second processing rule; wherein the plurality of second data components correspond to different frequencies respectively;

[0020] Based on the periodic and frequency band characteristics of the second data components, interference signals and valid seismic signals are distinguished from multiple second data components; and based on the distinguished interference signals and valid seismic signals, compressed sensing reconstruction is performed on the target seismic data after the first suppression.

[0021] In one embodiment, the target area includes a deep stratigraphic region; correspondingly, the frequency band characteristics are determined based on the stratigraphic characteristics of the deep stratigraphic region.

[0022] In one embodiment, according to preset detection rules, detecting whether the target seismic data after the second suppression meets preset requirements includes:

[0023] According to the preset detection rules, frequency-wavenumber spectrum analysis is performed on the target seismic data after the second suppression to obtain the corresponding analysis results;

[0024] Based on the analysis results, detect whether there are any abnormal indicator parameters;

[0025] If no abnormal indicator parameters are found, the target seismic data after the second suppression is determined to meet the preset requirements.

[0026] In one embodiment, the anomaly indication parameter includes: tilt angle anomaly indication parameter.

[0027] In one embodiment, if it is determined that the target seismic data after the second suppression does not meet preset requirements, the method further includes:

[0028] The target earthquake data after the second suppression is determined as the target earthquake data for the next round;

[0029] Shear transformation is performed on the next round of target seismic data to obtain multiple first data components;

[0030] According to the preset first processing rules and anomaly indication parameters, multiple first data components are processed; and by performing inverse shear transformation on the processed multiple first data components, the first type of mechanical interference is suppressed to obtain the first suppressed target seismic data.

[0031] According to the preset second processing rule, the target seismic data after the first suppression is compressed and reconstructed to suppress the second type of mechanical interference, and the target seismic data after the second suppression is obtained.

[0032] According to the preset detection rules, the target seismic data after the second suppression is checked to see if it meets the preset requirements.

[0033] This specification also provides a device for suppressing mechanical interference in seismic data, including:

[0034] An acquisition module is used to acquire target seismic data about a target area; wherein the target seismic data contains mechanical interference, and the mechanical interference includes at least a first type of mechanical interference and a second type of mechanical interference;

[0035] The decomposition module is used to perform shear transformation on the target seismic data to obtain multiple first data components; wherein the multiple first data components correspond to different frequency scales and dip directions respectively;

[0036] The first processing module is used to process multiple first data components according to a preset first processing rule; and to suppress the first type of mechanical interference by performing an inverse shear transformation on the processed multiple first data components to obtain the first suppressed target seismic data.

[0037] The second processing module is used to suppress second type mechanical interference by performing compressed sensing reconstruction on the first suppressed target seismic data according to the preset second processing rules, and to obtain the second suppressed target seismic data.

[0038] The detection module is used to detect whether the target seismic data after the second suppression meets the preset requirements according to the preset detection rules.

[0039] The determination module is used to determine the target seismic data after the second suppression as the target seismic data after suppressing mechanical interference, provided that the target seismic data after the second suppression meets the preset requirements.

[0040] This specification also provides a computer-readable storage medium storing computer instructions that, when executed by a processor, implement steps related to a method for suppressing mechanical interference with the seismic data.

[0041] Based on the method and apparatus for suppressing mechanical interference in seismic data provided in this specification, after acquiring target seismic data concerning a target area and containing at least first-type and second-type mechanical interference, the target seismic data can first be sheared to decompose it into multiple first data components corresponding to multiple different frequency scales and dip directions; then, the multiple first data components are processed according to a preset first processing rule; and by performing an inverse shearing transformation on the processed multiple first data components, the first-type mechanical interference is specifically suppressed to obtain the first-suppressed target seismic data; further, according to a preset second processing rule, the first-suppressed target seismic data is further processed... The target seismic data undergoes compressed sensing reconstruction to specifically suppress type II mechanical interference, resulting in second-suppressed target seismic data. Then, according to preset detection rules, the second-suppressed target seismic data is checked to see if it meets preset requirements. If it does, the suppression process ends, and the current second-suppressed target seismic data is designated as the target seismic data after suppressing mechanical interference. Otherwise, the current second-suppressed target seismic data is used as the target seismic data for the next round, and the above suppression process is repeated until second-suppressed target seismic data that meets the preset requirements is obtained. By combining shear transformation, inverse shear transformation, and compressed sensing reconstruction according to corresponding processing rules, complex mechanical interference, including at least type I and type II mechanical interference, can be effectively suppressed from the target seismic data. Simultaneously, damage to the effective seismic signals in the target seismic data can be avoided, resulting in high-precision and relatively complete target seismic data after suppressing mechanical interference. Attached Figure Description

[0042] To more clearly illustrate the embodiments of this specification, the accompanying drawings used in the embodiments will be briefly introduced below. The drawings described below are only some embodiments recorded in this specification. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0043] Figure 1 This is a flowchart illustrating a method for suppressing mechanical interference in seismic data provided in one embodiment of this specification.

[0044] Figure 2 This is a schematic diagram of the structural composition of an electronic device provided in one embodiment of this specification;

[0045] Figure 3 This is a schematic diagram of the structural composition of a device for suppressing mechanical interference with seismic data, provided in one embodiment of this specification.

[0046] Figure 4This is a schematic diagram of one embodiment of the method for suppressing mechanical interference with seismic data provided in the embodiments of this specification, applied in a scenario example.

[0047] Figure 5 This is a schematic diagram of one embodiment of the method for suppressing mechanical interference with seismic data provided in the embodiments of this specification, applied in a scenario example.

[0048] Figure 6 This is a schematic diagram of one embodiment of the method for suppressing mechanical interference with seismic data provided in the embodiments of this specification, applied in a scenario example.

[0049] Figure 7 This is a schematic diagram of one embodiment of the method for suppressing mechanical interference with seismic data provided in the embodiments of this specification, applied in a scenario example.

[0050] Figure 8 This is a schematic diagram of one embodiment of the method for suppressing mechanical interference with seismic data provided in the embodiments of this specification, applied in a scenario example. Detailed Implementation

[0051] To enable those skilled in the art to better understand the technical solutions in this specification, the technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. Based on the embodiments in this specification, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of this specification.

[0052] Considering that seismic data acquisition is often subject to various linear interferences from surrounding factories, hammers, drilling rigs, etc., the acquired seismic data packets contain complex mechanical interferences, such as multiple linear interferences with different dip angles and frequencies coexisting. This results in significant interference errors and low accuracy in the acquired seismic data, affecting its subsequent use.

[0053] Because the interference signals generated by such complex mechanical interferences have a high degree of overlap with the effective seismic signals in the seismic data, existing suppression methods can suppress some interferences to a certain extent, but cannot suppress the complex mechanical interferences in the seismic data comprehensively and effectively. Furthermore, in the process of suppressing interferences, existing suppression methods are also prone to damaging the effective seismic signals in the seismic data that have a high degree of overlap with the interference signals, resulting in the inability to obtain relatively complete seismic data.

[0054] To address the root cause of the aforementioned problems, this specification considers the sensitive directionality and good sparsity of shear transform. It proposes first performing a shear transform on the seismic data to decompose it into first data components that correspond to multiple different frequency scales and dip directions in detail. This allows for the identification of linear interferences with different dip angles from the seismic data based on these first data components. Furthermore, considering that mechanical interferences often exhibit dip angle differences from the effective seismic signal in the target seismic data, this specification identifies the first data components with discrepancies according to preset first processing rules. After appropriate settings are applied, an inverse shear transform is performed for the first suppression, effectively suppressing this type of interference and obtaining the first suppressed seismic data. Furthermore, considering that the seismic data after the first suppression still contains a type of mechanical interference whose dip angle overlaps with the effective seismic signal but whose frequency differs, this type of mechanical interference cannot be directly suppressed during the first suppression process. Also, considering that compressed sensing reconstruction can effectively distinguish mechanical interference with dip angles similar to the effective seismic signal, a corresponding compressed sensing reconstruction can be performed on the seismic data after the first suppression according to the preset second type of processing rules to specifically suppress this type of mechanical interference. Thus, by combining shear transform, inverse shear transform, and compressed sensing reconstruction on the target seismic data according to the corresponding processing rules, complex mechanical interference in the seismic data can be effectively suppressed, while avoiding damage to the effective seismic signal during the suppression process, resulting in high-precision and relatively complete seismic data.

[0055] Based on the above ideas, see Figure 1 As shown in the embodiments of this specification, a method for suppressing mechanical interference in seismic data is provided. In specific implementation, this method may include the following:

[0056] S101: Acquire target seismic data about the target area; wherein the target seismic data contains mechanical interference, and the mechanical interference includes at least type I mechanical interference and type II mechanical interference;

[0057] S102: Perform a shear transformation on the target seismic data to obtain multiple first data components; wherein, the multiple first data components correspond to different frequency scales and dip directions respectively;

[0058] S103: Process multiple first data components according to the preset first processing rules; and suppress the first type of mechanical interference by performing inverse shear transformation on the processed multiple first data components to obtain the first suppressed target seismic data;

[0059] S104: According to the preset second processing rule, the target seismic data after the first suppression is compressed and reconstructed to suppress the second type of mechanical interference, and the target seismic data after the second suppression is obtained.

[0060] S105: According to the preset detection rules, check whether the target seismic data after the second suppression meets the preset requirements;

[0061] S106: If the target seismic data after the second suppression meets the preset requirements, the target seismic data after the second suppression is determined as the target seismic data after suppressing mechanical interference.

[0062] In some embodiments, the target area may specifically include a deep formation region. This target area may contain oil or gas reservoirs.

[0063] In some embodiments, the target seismic data may specifically include target shot gathers or target seismic shot gather data collected for the target area.

[0064] The target seismic data acquired directly contains valid seismic signals, but may also contain interference signals caused by mechanical interference. This mechanical interference can specifically be a complex type of linear interference containing multiple frequencies and dip angles.

[0065] In some embodiments, the aforementioned mechanical interference may specifically include two types of mechanical interference: a first type of mechanical interference and a second type of mechanical interference.

[0066] In some embodiments, the first type of mechanical interference may specifically include: linear interference where the dip angle differs from the effective seismic signal in the target seismic data; the second type of mechanical interference may specifically include: linear interference where the dip angle is the same as the effective seismic signal in the target seismic data, but the frequency differs.

[0067] In some embodiments, the above-mentioned shear transformation has a sensitive directionality and good sparsity, and has multi-scale and multi-directional characteristics, which can characterize the tilt angle and frequency of complex mechanical disturbances in a relatively detailed manner.

[0068] In practice, the target seismic data can be decomposed into multiple data components by performing a shear transformation, resulting in multiple first data components. These multiple first data components correspond to different frequency scales and dip directions.

[0069] Specifically, the aforementioned frequency scale, also known simply as scale, typically represents low-frequency information with smaller scales and high-frequency information with larger scales. The aforementioned tilt direction, also known simply as direction, specifically refers to the tilt direction of linear interference in the frequency domain.

[0070] In some embodiments, before performing shear transformation on the target seismic data, frequency-wavenumber spectrum analysis can be performed on the target seismic data to obtain corresponding analysis results; based on the analysis results, dip angles and frequencies with a high probability of existence can be predicted; then, based on the dip angles and frequencies with a high probability of existence, targeted shear transformation can be performed on the target seismic data to decompose the target seismic data into multiple first data components with relatively better performance.

[0071] In some embodiments, during specific implementation, multiple first data components can be analyzed according to a preset first processing rule to filter out first data components whose dip angle and / or frequency are significantly different from the effective seismic signal, and these are denoted as the differential first data components. Then, inverse shear transformation is performed in combination with the differential first data components to perform the first suppression, so as to specifically suppress the first type of mechanical interference in the target seismic data and obtain the target seismic data after the first suppression.

[0072] In some embodiments, the above-described processing of multiple first data components according to a preset first processing rule, and the inverse shearing transformation of the processed multiple first data components, may specifically include the following:

[0073] S1: According to the preset first processing rule, obtain the seismic velocity of each of the multiple first data components;

[0074] S2: Based on the earthquake velocity, select the first data component with differences in dip angle and / or frequency from multiple first data components, and mark the first data component as the difference first data component;

[0075] S3: Set the shearing transform coefficient of the differential first data component among the multiple first data components to 0; and perform an inverse shearing transform on the multiple first data components after setting.

[0076] The shear transformation mentioned above is a spatial linear transformation, specifically a primitive transformation within affine transformations.

[0077] In this embodiment, firstly, considering that dip angle often corresponds to seismic velocity, differences in dip angle often map to differences in seismic velocity. Accordingly, the order of magnitude of the seismic velocity corresponding to an effective seismic signal is often significantly greater than the order of magnitude of the seismic velocity corresponding to mechanical interference. For example, the seismic velocity value corresponding to an effective seismic signal can reach 300 to 5000, while the seismic velocity value corresponding to mechanical interference with a difference in dip angle is only a few hundred. Based on the above considerations, the seismic velocities of each first data component can be acquired and, according to the seismic velocities, quickly filtered to identify the first data components with seismic velocities of only a few hundred and not exceeding 1000 as the first data components with differences in dip angle and / or frequency, i.e., the differential first data components (corresponding to the first type of mechanical interference). Specifically, the aforementioned first data components can be data components with large dip angles and / or low frequencies.

[0078] Furthermore, it is possible to selectively suppress the first type of mechanical interference by filtering out the aforementioned first data components. Specifically, the shear transform coefficients of the differential first data components can be set to 0 firstly, and then inverse shear transform can be performed on multiple first data components to recover shot gather data, thus obtaining the target seismic data after the first suppression. Here, the target seismic data after the first suppression refers to the target seismic data after the first type of mechanical interference has been suppressed.

[0079] Typically, when the shearing direction coincides with the linear interference, the coefficients of the shearing transformation are larger and differ from those of other shearing directions. Setting the shearing transformation coefficients corresponding to linear interference with large tilt angles and / or low frequencies to 0 and then performing the inverse shearing transformation can effectively suppress type I mechanical interference.

[0080] In some embodiments, in specific implementations, frequency-wavenumber spectrum analysis can be performed on multiple first data components to obtain corresponding analysis results; then, based on the analysis results, first data components with differences in tilt angle and / or frequency can be selected. For example, first data components with large tilt angle and small frequency.

[0081] In some embodiments, during specific implementation, multiple second data components corresponding to different frequencies can be separated from the target seismic data after the first suppression according to the preset second processing rules; after determining the second data components with the same (or overlapping) dip angle as the effective seismic signal but different frequency, sensing compression reconstruction is performed to perform a second suppression, so as to specifically suppress the second type of mechanical interference in the target seismic data after the first suppression, and obtain the target seismic data after the second suppression.

[0082] In some embodiments, the above-mentioned compressed sensing reconstruction of the target seismic data after the first suppression, according to a preset second processing rule, may specifically include the following:

[0083] S1: According to the preset second processing rule, the target seismic data after the first suppression is split into multiple second data components; wherein, the multiple second data components correspond to different frequencies;

[0084] S2: Acquire and distinguish interference signals and valid seismic signals from multiple second data components based on the periodicity and frequency band characteristics of the second data components; and perform compressed sensing reconstruction on the target seismic data after the first suppression based on the distinguished interference signals and valid seismic signals.

[0085] In this embodiment, when implementing it, firstly, considering that the target seismic data after the first suppression often contains linear interference with dip angles that overlap with the effective seismic signal but with frequencies different from the effective seismic signal, in order to suppress the above interference, the target seismic data after the first suppression can be split into multiple second data components corresponding to different frequencies.

[0086] Furthermore, considering that the target area of ​​interest often belongs to deep strata, the corresponding frequency band differs from that of mechanical interference. In addition, mechanical interference is mostly generated through mechanical vibration and often exhibits significant periodicity, such as a relatively consistent peak appearing at fixed time intervals. Therefore, based on the periodicity and frequency band characteristics of the second data components corresponding to different frequencies, we can first meticulously identify interference signals with significantly different periodicity and frequency band characteristics from multiple second data components. After distinguishing between the interference signals and the effective seismic signals, we then perform compressed sensing reconstruction on the target seismic data after the first suppression to specifically suppress the second type of mechanical interference still present in the target seismic data after the first suppression, thus obtaining the target seismic data after the second suppression.

[0087] In some embodiments, the target area may specifically include a deep stratum region; correspondingly, the frequency band characteristics may be determined based on the stratigraphic characteristics of the deep stratum region.

[0088] In some embodiments, frequency-wavenumber spectrum analysis can be performed on multiple second data components to obtain corresponding analysis results. Then, based on the analysis results, as well as the periodicity and frequency band characteristics of the second data components, interference signals and valid seismic signals can be more accurately distinguished from the multiple second data components.

[0089] In some embodiments, the above-mentioned detection of whether the target seismic data after the second suppression meets the preset requirements according to the preset detection rules may include the following:

[0090] S1: According to the preset detection rules, perform frequency-wavenumber spectrum analysis on the target seismic data after the second suppression to obtain the corresponding analysis results;

[0091] S2: Based on the analysis results, detect whether there are any abnormal indicator parameters;

[0092] S3: If it is determined that there are no abnormal indicator parameters, the target seismic data after the second suppression meets the preset requirements.

[0093] In some embodiments, the anomaly indication parameters may specifically include tilt angle anomaly indication parameters, etc. Besides tilt angle anomaly indication parameters, the aforementioned anomaly indication parameters may also include frequency anomaly indication parameters.

[0094] In practice, based on the anomaly indication parameters in the analysis results obtained from frequency-wavenumber spectrum analysis, it is determined whether there is still mechanical interference in the target seismic data after the second suppression, where the dip angle and / or frequency differs from the effective seismic signal.

[0095] Specifically, if it is determined that there are no abnormal indicator parameters, it can be determined that there is no mechanical interference in the current target seismic data after the second suppression that differs from the effective seismic signal in dip angle and / or frequency. Therefore, it can be determined that the current target seismic data after the second suppression meets the preset requirements. At this time, the current target seismic data after the second suppression can be identified as the target seismic data after suppressing mechanical interference, and the suppression process ends.

[0096] Conversely, if anomaly indicator parameters are identified, it can be determined that the current target seismic data after the second suppression still contains mechanical interference with dip angle and / or frequency that differs from the effective seismic signal. Consequently, it can be determined that the current target seismic data after the second suppression does not meet the preset requirements. In this case, the target seismic data after the second suppression cannot be identified as the target seismic data after suppressing mechanical interference, and the next round of suppression processing can be triggered.

[0097] In some embodiments, when it is determined that the target seismic data after the second suppression does not meet the preset requirements, the method may further include the following:

[0098] S1: The target seismic data after the second suppression is determined as the target seismic data for the next round;

[0099] S2: Perform a shear transformation on the next round of target seismic data to obtain multiple first data components;

[0100] S3: Process multiple first data components according to the preset first processing rules and anomaly indication parameters; and suppress the first type of mechanical interference by performing inverse shear transformation on the processed multiple first data components to obtain the first suppressed target seismic data;

[0101] S4: According to the preset second processing rule, the target seismic data after the first suppression is compressed and reconstructed to suppress the second type of mechanical interference, and the target seismic data after the second suppression is obtained.

[0102] S5: According to the preset detection rules, check whether the target seismic data after the second suppression meets the preset requirements.

[0103] In this embodiment, when processing multiple first data components according to the preset first processing rules and tilt anomaly indication parameters, the first data components that still have tilt angle differences can be selectively selected as the difference first data components based on the tilt angle indicated by the tilt angle anomaly indication parameters; then, after setting the shear transformation coefficient of the difference first data components to 0, an inverse shear transformation is performed to more effectively suppress the remaining first type of mechanical disturbance.

[0104] Similarly, the target seismic data after the first suppression can be compressed and reconstructed according to the preset second processing rules and frequency anomaly indication parameters, so as to more effectively suppress the remaining second type of mechanical interference.

[0105] Furthermore, the target seismic data after the second suppression can be tested according to the preset detection rules. If it still does not meet the preset requirements, the suppression process can be repeated multiple times in the above manner until the target seismic data after the second suppression finally meets the preset requirements.

[0106] In some embodiments, the shearlet transform can be used instead of the shearing transform for the first compression process. The shearlet transform also possesses the property of effectively representing image features sparsely.

[0107] In some embodiments, after determining the target seismic data after the second suppression as the target seismic data after suppressing mechanical interference, the method may further include: conducting oil and gas exploration in the target area based on the target seismic data after suppressing mechanical interference. This allows for more precise oil and gas exploration in the target area by utilizing the target seismic data with relatively high accuracy and relatively small error after suppressing mechanical interference.

[0108] As can be seen from the above, the method for suppressing mechanical interference in seismic data provided in the embodiments of this specification, after obtaining target seismic data concerning the target area and containing at least first-type and second-type mechanical interference, can first decompose the target seismic data into multiple first data components corresponding to different frequency scales and dip directions by performing a shear transformation on the target seismic data; then process the multiple first data components according to a preset first processing rule; and suppress the first-type mechanical interference by performing an inverse shear transformation on the processed multiple first data components to obtain the first suppressed target seismic data; further, according to a preset second processing rule, suppress the second-type mechanical interference by performing compressed sensing reconstruction on the first suppressed target seismic data to obtain the second suppressed target seismic data; then, according to a preset detection rule, detect whether the above-mentioned second suppressed target seismic data meets the preset requirements; and if it is determined that the second suppressed target seismic data meets the preset requirements, determine that the suppression processing is finished, and determine the current second suppressed target seismic data as the target seismic data after suppressing mechanical interference. By combining shear transformation, inverse shear transformation, and compressed sensing reconstruction on the target seismic data according to the corresponding processing rules, it is possible to effectively suppress complex mechanical interferences in the target seismic data, which contain at least type I and type II mechanical interferences, while avoiding damage to the effective seismic signals in the target seismic data, thus obtaining target seismic data with higher accuracy and more complete data.

[0109] This specification also provides an electronic device, including a processor and a memory for storing processor-executable instructions. Specifically, the processor can perform the following steps according to the instructions: acquiring target seismic data about a target area; wherein the target seismic data contains mechanical interference, which includes at least a first type of mechanical interference and a second type of mechanical interference; performing a shearing transformation on the target seismic data to obtain multiple first data components; wherein the multiple first data components correspond to different frequency scales and dip directions; processing the multiple first data components according to a preset first processing rule; and suppressing the first type of mechanical interference by performing an inverse shearing transformation on the processed multiple first data components to obtain first suppressed target seismic data; suppressing the second type of mechanical interference by performing compressed sensing reconstruction on the first suppressed target seismic data according to a preset second processing rule to obtain second suppressed target seismic data; detecting whether the second suppressed target seismic data meets preset requirements according to preset detection rules; and determining the second suppressed target seismic data as target seismic data after suppressing mechanical interference if it is determined that the second suppressed target seismic data meets the preset requirements.

[0110] To execute the above instructions more accurately, please refer to... Figure 2As shown in the embodiments of this specification, another specific electronic device is also provided, wherein the electronic device includes a network communication port 201, a processor 202 and a memory 203, and the above structures are connected by internal cables so that the various structures can perform specific data interaction.

[0111] Specifically, the network communication port 201 can be used to acquire target seismic data about the target area; wherein the target seismic data packet contains mechanical interference, and the mechanical interference includes at least a first type of mechanical interference and a second type of mechanical interference.

[0112] The processor 202 is specifically configured to perform a shearing transformation on the target seismic data to obtain multiple first data components, wherein the multiple first data components correspond to different frequency scales and dip directions; process the multiple first data components according to a preset first processing rule; and suppress first-type mechanical interference by performing an inverse shearing transformation on the processed multiple first data components to obtain first-suppressed target seismic data; suppress second-type mechanical interference by performing compressed sensing reconstruction on the first-suppressed target seismic data according to a preset second processing rule to obtain second-suppressed target seismic data; detect whether the second-suppressed target seismic data meets preset requirements according to preset detection rules; and determine the second-suppressed target seismic data as the target seismic data after suppressing mechanical interference if it is determined that the second-suppressed target seismic data meets the preset requirements.

[0113] The memory 203 can be used to store the corresponding instruction program.

[0114] In this embodiment, the network communication port 201 can be a virtual port bound to different communication protocols, thereby enabling the sending or receiving of different data. For example, the network communication port can be a port responsible for web data communication, a port responsible for FTP data communication, or a port responsible for email data communication. Furthermore, the network communication port can also be a physical communication interface or communication chip. For example, it can be a wireless mobile network communication chip, such as GSM or CDMA; it can also be a Wi-Fi chip; or it can be a Bluetooth chip.

[0115] In this embodiment, the processor 202 can be implemented in any suitable manner. For example, the processor can take the form of a microprocessor or processor and a computer-readable medium storing computer-readable program code (e.g., software or firmware) executable by the (micro)processor, logic gates, switches, application-specific integrated circuits (ASICs), programmable logic controllers, and embedded microcontrollers, etc. This specification is not limiting.

[0116] In this embodiment, the memory 203 may include multiple layers. In a digital system, anything that can store binary data can be a memory. In an integrated circuit, a circuit with storage function but no physical form is also called a memory, such as RAM, FIFO, etc. In a system, a storage device with a physical form is also called a memory, such as a memory stick, TF card, etc.

[0117] This specification also provides a computer-readable storage medium for a method of suppressing mechanical interference based on the above-mentioned seismic data. The computer-readable storage medium stores computer program instructions that, when executed, implement the following: acquiring target seismic data about a target area; wherein the target seismic data contains mechanical interference, which includes at least a first type of mechanical interference and a second type of mechanical interference; performing a shearing transformation on the target seismic data to obtain multiple first data components; wherein the multiple first data components correspond to different frequency scales and dip directions; processing the multiple first data components according to a preset first processing rule; and suppressing the first type of mechanical interference by performing an inverse shearing transformation on the processed multiple first data components to obtain first-suppressed target seismic data; suppressing the second type of mechanical interference by performing compressed sensing reconstruction on the first-suppressed target seismic data according to a preset second processing rule to obtain second-suppressed target seismic data; detecting whether the second-suppressed target seismic data meets preset requirements according to preset detection rules; and determining the second-suppressed target seismic data as the target seismic data after suppressing mechanical interference if it is determined that the second-suppressed target seismic data meets the preset requirements.

[0118] In this embodiment, the storage medium includes, but is not limited to, Random Access Memory (RAM), Read-Only Memory (ROM), cache, hard disk drive (HDD), or memory card. The memory can be used to store computer program instructions. The network communication unit can be an interface configured according to standards specified in the communication protocol for network connection communication.

[0119] In this embodiment, the specific functions and effects implemented by the program instructions stored in the computer-readable storage medium can be explained in comparison with other embodiments, and will not be repeated here.

[0120] See Figure 3 As shown, at the software level, this specification also provides a device for suppressing mechanical interference in seismic data, which may specifically include the following structural modules:

[0121] The acquisition module 301 can be specifically used to acquire target seismic data about a target area; wherein, the target seismic data packet contains mechanical interference, and the mechanical interference includes at least a first type of mechanical interference and a second type of mechanical interference;

[0122] The decomposition module 302 can be used to perform shear transformation on the target seismic data to obtain multiple first data components; wherein the multiple first data components correspond to different frequency scales and dip directions respectively;

[0123] The first processing module 303 is specifically used to process multiple first data components according to a preset first processing rule; and to suppress the first type of mechanical interference by performing an inverse shear transformation on the processed multiple first data components to obtain the first suppressed target seismic data.

[0124] The second processing module 304 can be used to suppress second type mechanical interference by performing compressed sensing reconstruction on the first suppressed target seismic data according to the preset second processing rules, and obtain the second suppressed target seismic data.

[0125] The detection module 305 can be used to detect whether the target seismic data after the second suppression meets the preset requirements according to the preset detection rules.

[0126] The determination module 306 can be used to determine the target seismic data after the second suppression as the target seismic data after suppressing mechanical interference, provided that the target seismic data after the second suppression meets the preset requirements.

[0127] In some embodiments, the first type of mechanical interference may specifically include: linear interference where the dip angle differs from the effective seismic signal in the target seismic data; the second type of mechanical interference may specifically include: linear interference where the dip angle is the same as the effective seismic signal in the target seismic data, but the frequency differs.

[0128] In some embodiments, when the first processing module 303 is specifically implemented, it can process multiple first data components according to a preset first processing rule in the following manner; and perform an inverse shear transformation on the processed multiple first data components: according to the preset first processing rule, obtain the seismic velocity of each of the multiple first data components; according to the seismic velocity, select the first data components with differences in dip angle and / or frequency from the multiple first data components, and mark the first data components as differential first data components; set the shear transformation coefficient of the differential first data components in the multiple first data components to 0; and perform an inverse shear transformation on the set multiple first data components.

[0129] In some embodiments, when the second processing module 304 is specifically implemented, it can perform compressed sensing reconstruction on the target seismic data after the first suppression according to the preset second processing rules in the following manner: according to the preset second processing rules, the target seismic data after the first suppression is split into multiple second data components; wherein, the multiple second data components correspond to different frequencies; the periodicity and frequency band characteristics of the second data components are acquired and the interference signal and the valid seismic signal are distinguished from the multiple second data components; and the target seismic data after the first suppression is reconstructed based on the distinguished interference signal and the valid seismic signal.

[0130] In some embodiments, the target area may specifically include a deep stratum region; correspondingly, the frequency band characteristics may be determined based on the stratigraphic characteristics of the deep stratum region.

[0131] In some embodiments, when the detection module 305 is specifically implemented, it can detect whether the target seismic data after the second suppression meets the preset requirements according to the preset detection rules in the following manner: according to the preset detection rules, perform frequency-wavenumber spectrum analysis on the target seismic data after the second suppression to obtain the corresponding analysis results; according to the analysis results, detect whether there are abnormal indicator parameters; if it is determined that there are no abnormal indicator parameters, determine that the target seismic data after the second suppression meets the preset requirements.

[0132] In some embodiments, the anomaly indication parameters may specifically include tilt angle anomaly indication parameters. Furthermore, the aforementioned anomaly indication parameters may also include frequency anomaly indication parameters, etc.

[0133] In some embodiments, when it is determined that the target seismic data after the second suppression does not meet the preset requirements, the device may further be used to determine the target seismic data after the second suppression as the target seismic data for the next round; perform a shearing transformation on the target seismic data for the next round to obtain multiple first data components; process the multiple first data components according to a preset first processing rule and anomaly indication parameters; suppress first-type mechanical interference by performing an inverse shearing transformation on the processed multiple first data components to obtain the target seismic data after the first suppression; suppress second-type mechanical interference by performing compressed sensing reconstruction on the target seismic data after the first suppression according to a preset second processing rule to obtain the target seismic data after the second suppression; and detect whether the target seismic data after the second suppression meets the preset requirements according to a preset detection rule.

[0134] It should be noted that the units, devices, or modules described in the above embodiments can be implemented by computer chips or physical entities, or by products with certain functions. For ease of description, the above devices are described by dividing them into various modules according to their functions. Of course, in implementing this specification, the functions of each module can be implemented in one or more software and / or hardware, or the module that implements the same function can be implemented by a combination of multiple sub-modules or sub-units, etc. The device embodiments described above are merely illustrative. For example, the division of units is only a logical functional division, and there may be other division methods in actual implementation. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection between the devices or units shown or discussed can be through some interfaces, and the indirect coupling or communication connection between devices or units can be electrical, mechanical, or other forms.

[0135] As can be seen from the above, the mechanical interference suppression device for seismic data provided in the embodiments of this specification, by combining shear transformation, inverse shear transformation and compressed sensing reconstruction on the target seismic data according to the corresponding processing rules, can effectively suppress complex mechanical interference in the target seismic data, which contains at least the first type of mechanical interference and the second type of mechanical interference, while avoiding damage to the effective seismic signal in the target seismic data, and obtain target seismic data with high accuracy and relatively completeness.

[0136] In a specific scenario example, the method and apparatus for suppressing mechanical interference in seismic data provided in this specification can be applied to suppress complex mechanical interference in the seismic data of region A. For detailed implementation procedures, please refer to [link / reference needed]. Figure 4 As shown, it may include the following:

[0137] S401: Use shear transformation to decompose seismic shot gather data into multiple scales and directions to obtain data components of different scales and different shear directions (equivalent to performing shear transformation on the target seismic data to obtain multiple first data components).

[0138] In this scenario embodiment, seismic data can be acquired first in area A to obtain seismic shot gather data (or raw seismic shot gather, for example, target seismic data of the target area) for area A.

[0139] For details, please refer to Figure 5 As shown. Among them, Figure 5 (a) in the image represents the original seismic shot collection; Figure 5 (b) shows the specific distribution of the original seismic shot gather and linear interference on the frequency-wavenumber spectrum obtained through frequency-wavenumber spectrum analysis. Combined with... Figure 5As shown in (a) and (b), the original seismic shot gather exhibits a complex combination of linear interference caused by external mechanical disturbances (e.g., complex mechanical disturbances to be suppressed). It is evident that the original seismic shot gather contains multiple sets of linear interferences with different dip angles and frequencies, including: linear interferences with a large difference between the dip angle and the effective seismic signal (corresponding to interference 1 marked with a rectangle, i.e., the first type of mechanical interference), and linear interferences with dip angles overlapping with the effective seismic signal but differing in frequency (corresponding to interference 2 marked with a rectangle, i.e., the second type of mechanical interference).

[0140] For the aforementioned linear interference combinations, based on shear transform and inverse shear transform, when the dip angle reflected by the frequency-wavenumber spectrum differs significantly from the effective signal, its distribution area can be completely separated from the effective signal, and this type of interference can be effectively suppressed using dip angle information; however, linear interference where the dip angle completely overlaps with the effective seismic signal cannot be effectively separated.

[0141] In this scenario example, the scale mentioned above refers to the frequency scale, with smaller scales corresponding to low-frequency information and larger scales corresponding to high-frequency information; the direction refers to the direction of the frequency domain linear interference tilt angle.

[0142] S402: Set the shear coefficient of linear interference components with dip angle and frequency that differ significantly from the effective seismic signal to 0, and restore the seismic shot gather data by inverse shear transformation to suppress some linear interference.

[0143] In this scenario example, when the shearing direction is consistent with the linear interference, the coefficient of the shearing transformation is larger and differs from that of other shearing directions. The shearing transformation coefficient corresponding to the linear interference with large dip angle and low frequency can be set to 0, and the shot gather data can be recovered through inverse shearing transformation, thereby suppressing the linear interference with large dip angle and low frequency (i.e., the first type of mechanical interference).

[0144] For details, please refer to Figure 6 As shown, where, Figure 6 (a) in the image represents the original seismic shot collection; Figure 6 (b) in the figure is the result obtained after suppressing linear interference with large dip angle and low frequency (e.g., target seismic data after the first suppression). In this case, only linear interference with the same dip angle as the effective seismic signal exists in the result (e.g., the part marked by the rectangle). Figure 6 In the middle (c), the linear interference with large dip angle and low frequency that was removed is shown. There is no effective seismic signal on the linear interference map. It can be seen that the method can effectively avoid the damage to the effective seismic signal in the seismic data during the suppression process.

[0145] S403: For seismic shot gathers that have suppressed some linear interference, compressed sensing reconstruction method is used to suppress linear interference whose dip angle overlaps with the effective seismic signal but whose frequency differs from the effective seismic signal.

[0146] In this scenario example, compressed sensing reconstruction is used to suppress linear interference (i.e., type II mechanical interference) that overlaps with the effective seismic signal at the remaining dip angle but has a different frequency.

[0147] For details, please refer to Figure 7 As shown, where, Figure 7 (a) in the image shows the seismic shot set before compressed sensing reconstruction. At this time, the seismic shot set still contains linear interference (data selected by the rectangular box) where the dip angle overlaps with the effective seismic signal but the frequency is different from the effective seismic signal. Figure 7 In Figure (b), the seismic shot gather undergoes compressed sensing reconstruction. In this case, there is no linear interference in the shot gather where the dip angle overlaps with the effective seismic signal but the frequency differs. This demonstrates that the compressed sensing reconstruction method can suppress linear interference where the dip angle overlaps with the effective seismic signal but the frequency differs.

[0148] S404: Perform frequency-wavenumber spectrum analysis on seismic shot gather data to confirm the parameter selection and processing effect of using combined advantages to suppress complex mechanical interference.

[0149] In this scenario example, frequency-wavenumber spectrum analysis can be performed on the seismic shot gather data obtained in step 403, and the suppression can be terminated based on the analysis results. If it is determined that mechanical interference still exists in the current seismic shot gather, a more suitable parameter combination can be selected based on the analysis results, and the above steps can be repeated until there is no more mechanical interference in the obtained seismic shot gather, at which point the suppression can be terminated.

[0150] For details, please refer to Figure 8 As shown. Among them, Figure 8 (a) in the figure represents the frequency-wavenumber spectrum of the pre-processed seismic shot gather data; Figure 8 (b) in the image shows the frequency-wavenumber spectrum of the seismic shot gather data after suppressing the first type of mechanical interference (linear interference with large dip angle and low frequency). Figure 8 (c) in the figure represents the frequency-wavenumber spectrum of the seismic shot gather data after suppressing the second type of mechanical interference (linear interference whose dip angle overlaps with the effective seismic signal but whose frequency differs from the effective seismic signal).

[0151] based on Figure 8 It can be seen that, by comparing the frequency-wavenumber spectrum of the seismic shot gather data before and after processing, the region where the dip angle overlaps with the effective seismic signal (corresponding to the region selected by the rectangular box) shows that, after combined processing, the energy within the rectangular box on the frequency-wavenumber spectrum has changed, all linear interference has been eliminated, but the energy of the effective seismic signal is still well preserved.

[0152] The above scenario examples illustrate that when the frequency and dip angle of linear noise overlap with the effective signal, existing denoising methods based on the frequency-wavenumber domain, time-frequency domain, and simple time domain often have poor suppression effects on complex mechanical interference. However, the mechanical interference suppression method based on seismic data provided in this specification first fully utilizes shear transform to meticulously characterize the dip angle and frequency of complex mechanical interference, obtaining more detailed directional components. This facilitates the differentiation of linear interference with different dip angles from the seismic data, effectively eliminating the first type of linear interference with large dip angles and low frequencies. Furthermore, by fully utilizing compressed sensing reconstruction methods, the characteristics of linear interference with dip angles similar to the effective seismic signal can be effectively identified, allowing for the effective suppression of the second type of linear interference—those with dip angles overlapping with the effective seismic signal but different frequencies. Therefore, shear transform and compressed sensing can be combined to effectively suppress both types of mechanical interference while avoiding damage to the effective seismic signal in the seismic data.

[0153] While this specification provides the steps of operation for the methods described in the embodiments or flowcharts, more or fewer steps may be included based on conventional or non-inventive means. The order of steps listed in the embodiments is merely one possible order of execution among many steps and does not represent the only possible order. In actual device or client product execution, the methods shown in the embodiments or drawings may be executed sequentially or in parallel (e.g., in a parallel processor or multi-threaded processing environment, or even a distributed data processing environment). The terms "comprising," "including," or any other variations thereof are intended to cover a non-exclusive inclusion, such that a process, method, product, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, product, or apparatus. Without further limitations, the presence of other identical or equivalent elements in a process, method, product, or apparatus that includes said elements is not excluded. The terms "first," "second," etc., are used to denote names and do not indicate any particular order.

[0154] Those skilled in the art will also know that, besides implementing the controller using purely computer-readable program code, the same functions can be achieved by logically programming the method steps, making the controller function as logic gates, switches, application-specific integrated circuits (ASICs), programmable logic controllers (PLCs), and embedded microcontrollers. Therefore, such a controller can be considered a hardware component, and the devices within it used to implement various functions can also be considered structures within that hardware component. Alternatively, the devices used to implement various functions can be considered as both software modules implementing the method and structures within a hardware component.

[0155] This specification can be described in the general context of computer-executable instructions that are executed by a computer, such as program modules. Generally, program modules include routines, programs, objects, components, data structures, classes, etc., that perform a specific task or implement a specific abstract data type. This specification can also be practiced in distributed computing environments, where tasks are performed by remote processing devices connected via a communication network. In distributed computing environments, program modules can reside in local and remote computer-readable storage media, including storage devices.

[0156] As can be seen from the above description of the embodiments, those skilled in the art can clearly understand that this specification can be implemented by means of software plus necessary general-purpose hardware platforms. Based on this understanding, the technical solutions of this specification can essentially be embodied in the form of a software product. This computer software product can be stored in a storage medium, such as ROM / RAM, magnetic disk, optical disk, etc., and includes several instructions to cause a computer device (which may be a personal computer, mobile terminal, electronic device, or network device, etc.) to execute the methods described in the various embodiments or some parts of the embodiments of this specification.

[0157] The various embodiments in this specification are described in a progressive manner. Similar or identical parts between embodiments can be referred to interchangeably. Each embodiment focuses on its differences from other embodiments. This specification can be used in numerous general-purpose or special-purpose computer system environments or configurations. Examples include: personal computers, electronic computer, handheld or portable devices, tablet devices, multiprocessor systems, microprocessor-based systems, set-top boxes, programmable electronic devices, network PCs, minicomputers, mainframe computers, and distributed computing environments including any of the above systems or devices, etc.

[0158] Although this specification has been described by way of examples, those skilled in the art will recognize that many variations and modifications are possible without departing from the spirit of this specification, and it is intended that the appended claims cover such variations and modifications without departing from the spirit of this specification.

Claims

1. A method for suppressing mechanical interference in seismic data, characterized in that, include: Acquire target seismic data about a target area; wherein the target seismic data contains mechanical interference, the mechanical interference including at least a first type of mechanical interference and a second type of mechanical interference; the first type of mechanical interference includes: linear interference whose dip angle differs from the effective seismic signal in the target seismic data; the second type of mechanical interference includes: linear interference whose dip angle is the same as the effective seismic signal in the target seismic data, but whose frequency differs; The target seismic data is sheared to obtain multiple first data components; wherein the multiple first data components correspond to different frequency scales and dip directions. Multiple first data components are processed according to a preset first processing rule; and first type of mechanical interference is suppressed by performing an inverse shear transformation on the processed multiple first data components to obtain the first suppressed target seismic data; including: obtaining the seismic velocity of each of the multiple first data components according to the preset first processing rule; selecting first data components with differences in dip angle and / or frequency from the multiple first data components according to the seismic velocity, and marking the first data components as differential first data components; setting the shear transformation coefficient of the differential first data components among the multiple first data components to 0; and performing an inverse shear transformation on the set multiple first data components; According to the preset second processing rule, the target seismic data after the first suppression is compressed and reconstructed to suppress the second type of mechanical interference, and the target seismic data after the second suppression is obtained. According to the preset detection rules, the target seismic data after the second suppression is checked to see if it meets the preset requirements; If the target seismic data after the second suppression meets the preset requirements, the target seismic data after the second suppression is determined as the target seismic data after suppressing mechanical interference.

2. The method according to claim 1, characterized in that, According to the preset second processing rule, compressed sensing reconstruction is performed on the target seismic data after the first suppression, including: According to the preset second processing rule, the target seismic data after the first suppression is split into multiple second data components; wherein, the multiple second data components correspond to different frequencies. Based on the periodic and frequency band characteristics of the second data components, interference signals and valid seismic signals are distinguished from multiple second data components; and based on the distinguished interference signals and valid seismic signals, compressed sensing reconstruction is performed on the target seismic data after the first suppression.

3. The method according to claim 2, characterized in that, The target area includes deep geological strata; correspondingly, the frequency band characteristics are determined based on the geological characteristics of the deep geological strata.

4. The method according to claim 1, characterized in that, According to preset detection rules, the target seismic data after the second suppression is checked to see if it meets preset requirements, including: According to the preset detection rules, frequency-wavenumber spectrum analysis is performed on the target seismic data after the second suppression to obtain the corresponding analysis results; Based on the analysis results, detect whether there are any abnormal indicator parameters; If no abnormal indicator parameters are found, the target seismic data after the second suppression is determined to meet the preset requirements.

5. The method according to claim 4, characterized in that, The anomaly indication parameters include: tilt angle anomaly indication parameters.

6. The method according to claim 5, characterized in that, If the target seismic data after the second suppression is determined not to meet the preset requirements, the method further includes: The target earthquake data after the second suppression is determined as the target earthquake data for the next round; Shear transformation is performed on the next round of target seismic data to obtain multiple first data components; According to the preset first processing rules and anomaly indication parameters, multiple first data components are processed; and by performing inverse shear transformation on the processed multiple first data components, the first type of mechanical interference is suppressed to obtain the first suppressed target seismic data. According to the preset second processing rule, the target seismic data after the first suppression is compressed and reconstructed to suppress the second type of mechanical interference, and the target seismic data after the second suppression is obtained. According to the preset detection rules, the target seismic data after the second suppression is checked to see if it meets the preset requirements.

7. A device for suppressing mechanical interference in seismic data, characterized in that, include: An acquisition module is used to acquire target seismic data about a target area; wherein the target seismic data contains mechanical interference, the mechanical interference including at least a first type of mechanical interference and a second type of mechanical interference; the first type of mechanical interference includes linear interference whose dip angle differs from the effective seismic signal in the target seismic data; the second type of mechanical interference includes linear interference whose dip angle is the same as the effective seismic signal in the target seismic data, but whose frequency differs. The decomposition module is used to perform shear transformation on the target seismic data to obtain multiple first data components; wherein the multiple first data components correspond to different frequency scales and dip directions respectively; The first processing module is used to process multiple first data components according to a preset first processing rule; and to suppress the first type of mechanical interference by performing an inverse shear transformation on the processed multiple first data components to obtain the first suppressed target seismic data. The second processing module is used to suppress second type mechanical interference by performing compressed sensing reconstruction on the first suppressed target seismic data according to the preset second processing rules, and to obtain the second suppressed target seismic data. The detection module is used to detect whether the target seismic data after the second suppression meets the preset requirements according to the preset detection rules. The determination module is used to determine the target seismic data after the second suppression as the target seismic data after suppressing mechanical interference, provided that the target seismic data after the second suppression meets the preset requirements. Specifically, the first processing module is used to: obtain the seismic velocity of each of the multiple first data components according to a preset first processing rule; select the first data components with differences in dip angle and / or frequency from the multiple first data components according to the seismic velocity, and mark the first data components as the differential first data components; set the shear transform coefficient of the differential first data components in the multiple first data components to 0; and perform inverse shear transform on the multiple first data components after setting.

8. A computer-readable storage medium, characterized in that, It stores computer instructions that, when executed by a processor, implement the steps of the method according to any one of claims 1 to 6.

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