Method and apparatus for mechanical interference noise suppression, electronic device, and medium

Abstract

The present disclosure relates to a method and device for mechanical interference noise suppression, electronic equipment and medium, and relates to the technical field of signal processing, which comprises the following steps: screening a first seismic trace data set affected by mechanical interference source noise in seismic data; in the first seismic trace data set, taking the first target seismic trace closest to the mechanical interference source as the minimum offset to redefine the observation system, generating a second seismic trace data set under the new observation system; performing dynamic correction processing and tilt angle filtering denoising processing on the second seismic trace data set under the new observation system to obtain a third seismic trace data set; performing inverse dynamic correction processing on the third seismic trace data set, and performing observation system restoration processing on the processing result to obtain a fourth seismic trace data set after noise suppression corresponding to the original observation system. The present disclosure can improve the signal-to-noise ratio of the processing result, strengthen the target denoising without damaging other seismic data traces, has high processing efficiency, and saves processing resources.

Description

Technical Field

[0001] This disclosure relates to the field of signal processing technology, and in particular to a method, apparatus, electronic device, and medium for suppressing mechanical interference noise. Background Technology

[0002] During seismic data acquisition, various external interferences or self-resonance often result in linear noise and anomalous amplitudes in the data, severely impacting the high-precision imaging quality. Mechanical noise refers to noise caused by mechanical vibrations during seismic data acquisition. This noise affects the quality of the raw single-shot seismic data, thus impacting the quality and reliability of seismic exploration results. High-fidelity pre-stack preprocessing is a crucial step in the data processing of seismic data (or, as described, seismic data).

[0003] In realizing the present invention, the inventors discovered at least the following technical problems in the related technologies: the current technology for eliminating mechanical noise mainly involves filtering seismic data based on statistical effects of abnormal amplitudes. However, while removing mechanical noise, this method also easily filters out the effective reflection information mixed in with it. Some solutions convert conventional shot-domain seismic data into receiver domain or cross-domain for a certain degree of suppression. However, switching between domains between data can easily lead to the generation of large-scale volume data and is time-consuming to process. At the same time, due to the inherent characteristics of mechanical interference noise itself, this method cannot achieve precise suppression and is difficult to meet the needs of efficient exploration. Summary of the Invention

[0004] To solve the above-mentioned technical problems, or at least partially solve them, embodiments of this disclosure provide a method, apparatus, electronic device, and medium for suppressing mechanical interference noise.

[0005] In a first aspect, embodiments of this disclosure provide a method for suppressing mechanical interference noise. The method includes: filtering a first seismic trace dataset affected by noise from a mechanical interference source within seismic data; redefining the observation system within the first seismic trace dataset using a first target seismic trace closest to the mechanical interference source as the minimum offset, generating a second seismic trace dataset under the new observation system; performing dynamic correction processing for mechanical interference waves and tilt angle filtering denoising processing on the second seismic trace dataset under the new observation system to obtain a third seismic trace dataset; performing reaction correction processing on the third seismic trace dataset, and performing observation system restoration processing on the processing results to obtain a fourth seismic trace dataset corresponding to the original observation system after noise suppression.

[0006] In some embodiments, filtering a first seismic trace dataset affected by noise from a mechanical interference source in seismic data includes: determining the location information of the mechanical interference source based on actual exploration information; determining the influence range of the mechanical interference source based on noise measurement records; and filtering a first seismic trace dataset affected by noise from the mechanical interference source in the seismic data based on the location information of the mechanical interference source and the influence range. The noise measurement records are obtained by: deploying detection equipment at multiple key points within the expected influence area before or during actual exploration; and obtaining noise measurement records based on background vibration signals recorded by the detection equipment when the mechanical noise is turned on and off, wherein the background vibration signals are used to indicate the ground vibration signals when the detection equipment is turned on and off.

[0007] In some embodiments, determining the influence range of the mechanical interference source based on noise measurement records includes: comparing the spectral differences when the noise is on and off based on the background vibration signal to identify the target frequency component corresponding to the mechanical noise; calculating the noise amplitude or energy of the mechanical noise at different distances based on the target frequency component, and plotting the attenuation curve of the noise amplitude or energy as a function of distance; and comparing the attenuation curve with a set signal-to-noise ratio threshold to determine the distance range where the noise amplitude is lower than the signal-to-noise ratio threshold as the influence range of the mechanical interference source.

[0008] In some embodiments, the observation system is redefined using the first target seismic trace closest to the mechanical interference source as the minimum offset, generating a second seismic trace dataset under the new observation system. This includes: using the first target seismic trace closest to the mechanical interference source as the minimum offset position; for each first seismic trace at other locations besides the first target seismic trace, determining the virtual seismic trace shot-receiver offset corresponding to each first seismic trace based on the difference between the station number of each first seismic trace and the station number of the first target seismic trace; wherein the distance between traces is the same as the original receiver interval; and constructing the first target seismic trace and the first seismic traces represented by the virtual seismic trace shot-receiver offset into a second seismic trace dataset under the new observation system.

[0009] In some embodiments, dynamic correction processing of mechanical interference waves and tilt angle filtering denoising processing are performed on the second seismic trace dataset under the new observation system to obtain a third seismic trace dataset. This includes: determining the apparent velocity of mechanical noise corresponding to the second seismic trace dataset under the new observation system; using the apparent velocity of mechanical noise as the single-shot dynamic correction velocity to perform dynamic correction processing on the second seismic trace dataset; the processed seismic trace has low tilt angle characteristics; and based on Fourier transform, tilt angle filtering denoising processing is performed on the low-angle reflection phase axis of the dynamically corrected seismic trace to obtain the third seismic trace dataset.

[0010] In some embodiments, determining the apparent velocity of mechanical noise corresponding to the second seismic trace dataset under the new observation system includes: picking a clear and continuous noise in-phase axis segment in the second seismic trace dataset under the new observation system; and calculating the apparent velocity of mechanical noise based on the spatial distance difference and time difference corresponding to the picked noise in-phase axis segment.

[0011] In some embodiments, the method further includes merging the fourth seismic trace dataset with the fifth seismic trace dataset, which has been filtered out from the seismic data and is not affected by mechanical interference source noise, to obtain the target seismic single-shot dataset.

[0012] Secondly, embodiments of this disclosure provide an apparatus for suppressing mechanical interference noise. The apparatus includes: a screening module, an observation system conversion module, a denoising module, and an inverse conversion module. The screening module is used to screen a first seismic trace dataset affected by noise from a mechanical interference source in the seismic data. The observation system conversion module is used to redefine the observation system in the first seismic trace dataset, using the first target seismic trace closest to the mechanical interference source as the minimum offset, to generate a second seismic trace dataset under the new observation system. The denoising module is used to perform dynamic correction processing of the mechanical interference wave and tilt angle filtering denoising processing on the second seismic trace dataset under the new observation system to obtain a third seismic trace dataset. The inverse conversion module is used to perform inverse correction processing on the third seismic trace dataset and perform observation system restoration processing on the processing result to obtain a fourth seismic trace dataset corresponding to the original observation system after noise suppression.

[0013] Thirdly, embodiments of this disclosure provide an electronic device. The electronic device includes a processor, a communication interface, a memory, and a communication bus, wherein the processor, communication interface, and memory communicate with each other via the communication bus; the memory stores computer programs; and the processor, when executing the program stored in the memory, implements the method for suppressing mechanical interference noise as described above.

[0014] Fourthly, embodiments of this disclosure provide a computer-readable storage medium. The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method for suppressing mechanical interference noise as described above.

[0015] The technical solutions provided in the embodiments of this disclosure have at least some or all of the following advantages:

[0016] By filtering out the first seismic trace dataset affected by mechanical interference noise from seismic data, i.e., identifying seismic data segments affected by mechanical noise, target denoising can be enhanced without harming other seismic data traces. Furthermore, by redefining the observation system and generating a second seismic trace dataset under the new observation system, the seismic traces contaminated by mechanical noise have a virtual shot-receiver offset relationship, enabling subsequent dynamic correction processing and tilt angle filtering denoising. This scheme effectively removes mechanical noise without losing useful components of other seismic data. Moreover, it suppresses noise within a single shot domain, reducing data domain switching, significantly reducing processing time, and saving disk space. Overall, the above scheme improves the signal-to-noise ratio of the processed results, enhances target denoising without harming other seismic data traces, has fast seismic data processing efficiency, and saves processing resources. Attached Figure Description

[0017] The accompanying drawings, which are incorporated in and form a part of this specification, illustrate embodiments consistent with this disclosure and, together with the description, serve to explain the principles of this disclosure.

[0018] To more clearly illustrate the technical solutions in the embodiments of this disclosure or the prior art, the accompanying drawings used in the description of the embodiments or related technologies will be briefly introduced below. Obviously, those skilled in the art can obtain other drawings based on these drawings without creative effort.

[0019] Figure 1 A flowchart illustrating a method for suppressing mechanical interference noise according to an embodiment of the present disclosure is shown schematically.

[0020] Figure 2 A detailed implementation flowchart of step S110 according to an embodiment of the present disclosure is shown schematically.

[0021] Figure 3 A schematic diagram of raw single-shot data acquired by a controllable source according to an embodiment of the present disclosure is shown.

[0022] Figure 4 The diagram schematically illustrates (a) the result of filtering a first seismic trace dataset affected by mechanical interference noise in seismic data based on the location information and influence range of the mechanical interference source according to an embodiment of the present disclosure; (b) the result of redefining the observation system and generating a second seismic trace dataset under the new observation system; and (c) the schematic diagram of determining the apparent velocity of mechanical noise corresponding to the second seismic trace dataset under the new observation system.

[0023] Figure 5The diagram schematically illustrates (a) the result of dynamic correction processing of mechanical interference waves on a second seismic trace dataset under the new observation system described above, according to an embodiment of the present disclosure; (b) the result of tilt angle filtering and noise reduction processing on the low-angle reflection phase axis of the seismic trace after dynamic correction processing; and (c) the result obtained by further performing reaction correction processing.

[0024] Figure 6A The diagram illustrates the results of a mechanical noise processing scheme based on conventional methods. Figure 6B The diagram illustrates the result of seismic data processing based on the mechanical interference noise suppression method provided in the embodiments of this disclosure.

[0025] Figure 7 A schematic block diagram of an electronic device provided in an embodiment of the present disclosure is shown. Detailed Implementation

[0026] To make the objectives, technical solutions, and advantages of the embodiments of this disclosure clearer, the technical solutions of the embodiments of this disclosure will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of this disclosure. Based on the embodiments of this disclosure, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this disclosure.

[0027] With the deepening of seismic exploration, especially the widespread promotion and application of controlled-source seismic acquisition, large-scale, high-shot-density, high-efficiency seismic data acquisition has become the main trend in current exploration. High-efficiency exploration primarily relies on shortening the excitation time and distance between adjacent shots. However, a side effect of this high-efficiency approach is the widespread development of various types of noise, with a large impact area. Among these noises, mechanical noise is a significant type that seriously affects the imaging quality of seismic data. Mechanical noise refers to the noise caused by the mechanical vibration of machinery during seismic data acquisition. This noise affects the quality of the original single-shot seismic data, thereby impacting the quality and reliability of the seismic exploration results.

[0028] During the research and development process, it was found that current mechanical noise cancellation technologies mainly involve filtering seismic data based on statistical effects to detect abnormal amplitudes. Commonly used filtering methods include high-pass filtering, low-pass filtering, and band-pass filtering. These methods can suppress mechanical interference to some extent and improve the signal-to-noise ratio of seismic data by setting a certain frequency cutoff point to remove noise within a certain frequency range. However, the apparent velocity and frequency of mechanical interference are often mixed with effective reflection information, making it difficult to accurately identify and suppress. Conventional filtering may also filter out effective information in the seismic data, thus affecting the quality of the seismic data. In addition, some schemes often suppress mechanical noise by converting conventional shot-domain seismic data into receiver-domain or cross-domain data. However, switching between data domains can easily generate large-scale volumetric data and consume a lot of processing time. Furthermore, due to the inherent characteristics of mechanical interference noise itself, this method cannot achieve accurate suppression and is difficult to meet the needs of efficient exploration.

[0029] In view of this, embodiments of the present disclosure provide a method and apparatus for suppressing mechanical interference noise. The method includes: filtering a first seismic trace dataset affected by noise from a mechanical interference source in seismic data; redefining the observation system in the first seismic trace dataset by using the first target seismic trace closest to the mechanical interference source as the minimum offset, thereby generating a second seismic trace dataset under the new observation system; performing dynamic correction processing for mechanical interference waves and tilt angle filtering denoising processing on the second seismic trace dataset under the new observation system to obtain a third seismic trace dataset; performing reaction correction processing on the third seismic trace dataset and performing observation system restoration processing on the processing result to obtain a fourth seismic trace dataset corresponding to the original observation system after noise suppression.

[0030] By filtering out the first seismic trace dataset affected by mechanical interference noise from seismic data, i.e., identifying seismic data segments affected by mechanical noise, target denoising can be enhanced without harming other seismic data traces. Furthermore, by redefining the observation system and generating a second seismic trace dataset under the new observation system, the seismic traces contaminated by mechanical noise have a virtual shot-receiver offset relationship, enabling subsequent dynamic correction processing and tilt angle filtering denoising. This scheme effectively removes mechanical noise without losing useful components of other seismic data. Moreover, it suppresses noise within a single shot domain, reducing data domain switching, significantly reducing processing time, and saving disk space. Overall, the above scheme improves the signal-to-noise ratio of the processed results, enhances target denoising without harming other seismic data traces, has fast seismic data processing efficiency, and saves processing resources.

[0031] The embodiments of this disclosure will now be described in detail with reference to the accompanying drawings.

[0032] The first exemplary embodiment of this disclosure provides a method for suppressing mechanical interference noise. This method can be applied to electronic devices with computing capabilities.

[0033] Figure 1 A flowchart illustrating a method for suppressing mechanical interference noise according to an embodiment of the present disclosure is shown schematically.

[0034] Reference Figure 1 As shown, the method for suppressing mechanical interference noise provided in this embodiment includes the following steps: S110, S120, S130 and S140.

[0035] In step S110, the first seismic trace dataset affected by mechanical interference source noise is filtered from the seismic data.

[0036] In the embodiments of this disclosure, the seismic data are single-shot seismic data. A mechanical interference source refers to a mechanical source that generates mechanical vibrations, such as a controlled seismic source.

[0037] Figure 2 A detailed implementation flowchart of step S110 according to an embodiment of the present disclosure is shown schematically.

[0038] In some embodiments, refer to Figure 2 As shown, in step S110 above, the first seismic trace dataset affected by mechanical interference source noise is screened from the seismic data, which includes the following steps: S210, S220 and S230.

[0039] In step S210, the location information of the mechanical interference source is determined based on the actual exploration information.

[0040] By using actual exploration information, we can determine the equipment sources that can generate mechanical vibrations, such as the specific location of a controllable seismic source, and thus obtain the location information of the mechanical interference source.

[0041] In step S220, the influence range of the aforementioned mechanical interference source is determined based on the noise measurement records.

[0042] The noise measurement records are obtained in the following way: before or during the actual exploration, detection equipment is deployed at multiple key points in the expected impact area; based on the background vibration signals recorded by the detection equipment when the mechanical noise is turned on and off, noise measurement records are obtained, and the background vibration signals are used to indicate the ground vibration signals when the detection equipment is turned on and off.

[0043] In some embodiments, in step S220 above, determining the influence range of the mechanical interference source based on the noise measurement records includes:

[0044] Based on the background vibration signal, compare the spectral differences when the noise is on and off, and identify the target frequency components corresponding to the mechanical noise.

[0045] Based on the target frequency components mentioned above, the noise amplitude or energy of the mechanical noise at different distances is calculated, and the attenuation curves of the noise amplitude or energy as a function of distance are plotted.

[0046] Based on the comparison between the above attenuation curve and the set signal-to-noise ratio threshold, the distance range corresponding to the noise amplitude being lower than the above signal-to-noise ratio threshold is determined as the influence range of the above mechanical interference source.

[0047] In step S230, based on the location information of the mechanical interference source and the influence range, the first seismic trace dataset affected by the noise from the mechanical interference source is selected from the seismic data.

[0048] Figure 3 A schematic diagram of raw single-shot data acquired by a controllable source according to an embodiment of the present disclosure is shown. Figure 4 The diagram schematically illustrates (a) the result of filtering a first seismic trace dataset affected by mechanical interference noise in seismic data based on the location information and influence range of the mechanical interference source according to an embodiment of the present disclosure; (b) the result of redefining the observation system and generating a second seismic trace dataset under the new observation system; and (c) a diagram illustrating the determination of the apparent velocity of mechanical noise corresponding to the second seismic trace dataset under the new observation system. Figure 4 In (a) to (c), the green line is used to indicate the shot-receiver distance line.

[0049] Reference Figure 3 The diagram illustrates the raw single-shot data acquired by the controlled source with shot number 4719. By executing steps S210-S230, the first seismic trace dataset affected by mechanical interference noise was filtered from the seismic data. The results are referenced... Figure 4 As shown in (a), the first seismic trace dataset, which is affected by mechanical noise, is located to the left of the controllable source in the original single-shot data.

[0050] Based on steps S210-S230 above, the target seismic trace adjacent to the mechanical interference source in the seismic data can be located using the location information of the mechanical interference source. Using the target seismic trace as the center, an influence radius is constructed based on the influence range of the mechanical interference source (e.g., a distance parameter), and the interfered seismic data segment is determined, which is the first seismic trace dataset. The first seismic trace data in the first seismic trace dataset corresponds to the seismic traces within the aforementioned influence range.

[0051] In step S120, in the first seismic trace dataset mentioned above, the observation system is redefined with the first target seismic trace closest to the mechanical interference source as the minimum offset, and a second seismic trace dataset under the new observation system is generated.

[0052] In some embodiments, in step S120 above, the observation system is redefined using the first target seismic trace closest to the mechanical interference source as the minimum offset, and a second seismic trace dataset under the new observation system is generated, including:

[0053] The first target seismic trace closest to the mechanical interference source is taken as the minimum offset position;

[0054] For each first seismic trace at a location other than the aforementioned first target seismic trace, the virtual seismic trace shot-receiver distance corresponding to each first seismic trace is determined based on the difference between the station number of each first seismic trace and the station number of the aforementioned first target seismic trace; wherein, the distance between traces is the same as the original receiver interval distance.

[0055] The first target seismic trace and the first seismic trace represented by virtual seismic trace shot-receiver distance are constructed into the second seismic trace dataset under the new observation system.

[0056] For example, the raw shot-receiver offset of seismic data is temporarily stored in the data header. The process of storing the shot-receiver offset data is as follows:

[0057] SOURCE_DETECT_DISTANCE1= =SOURCE_DETECT_DISTANCE, (1)

[0058] Wherein, SOURCE_DETECT_DISTANCE1 represents the shot-receiver distance data temporarily stored in the data header; SOURCE_DETECT_DISTANCE represents the shot-receiver distance value to be stored; == represents the assignment operation.

[0059] Take the seismic trace closest to the mechanical interference source as the minimum offset seismic trace (or 0 shot-receiver distance), and read the station number information STN_DETECT0 of the corresponding receiver point for this seismic trace data.

[0060] The formula for converting the shot-detector distance at the detector point is defined as follows:

[0061] SOURCE_DETECT_DISTANCE2=STN_DETECT-STN_DETECT0; (2)

[0062] Wherein, SOURCE_DETECT_DISTANCE2 is the virtual seismic trace shot-receiver distance corresponding to each first seismic trace; STN_DETECT is the station number of each first seismic trace in the original observation system; STN_DETECT0 is the station number of the receiver point corresponding to the first target seismic trace closest to the mechanical interference source.

[0063] Based on the above conversion formula, it can be seen that in the original observation system, the offset distance corresponding to the small segment of the minimum shot-receiver distance seismic trace after conversion is negative in the new observation system; the offset distance corresponding to the large segment of the minimum offset seismic trace in the original observation system after conversion is positive in the new observation system; the farther away from the center point trace staircase STN_DETECT0, the larger the shot-receiver distance (offset distance); the closer to the center point trace staircase STN_DETECT0, the smaller the shot-receiver distance (offset distance).

[0064] Reference Figure 4 As shown in Figure (b), the results of the second seismic trace dataset generated under the new observation system after redefining the observation system are illustrated. The trace spacing between traces is the same as the original receiver spacing.

[0065] In step S130, the mechanical interference wave is dynamically corrected and the tilt angle is filtered and denoised for the second seismic trace dataset under the new observation system to obtain the third seismic trace dataset.

[0066] In some embodiments, in step S130 above, dynamic correction processing for mechanical interference waves and tilt angle filtering denoising processing are performed on the second seismic trace dataset under the new observation system to obtain the third seismic trace dataset, including:

[0067] Determine the apparent mechanical noise velocity corresponding to the second seismic trace dataset under the new observation system described above;

[0068] The apparent velocity of the mechanical noise mentioned above is used as the dynamic correction velocity of a single shot, and dynamic correction processing is performed on the second seismic trace dataset mentioned above; the processed seismic trace has low tilt angle characteristics.

[0069] Based on Fourier transform, the low-angle reflection phase axis of the seismic trace after dynamic correction is subjected to tilt angle filtering for noise reduction to obtain the third seismic trace dataset.

[0070] In some embodiments, determining the apparent velocity of mechanical noise corresponding to the second seismic trace dataset under the new observation system includes: picking a clear and continuous noise in-phase axis segment in the second seismic trace dataset under the new observation system; and calculating the apparent velocity of mechanical noise based on the spatial distance difference and time difference corresponding to the picked noise in-phase axis segment.

[0071] For example, refer to Figure 4As shown in (c), the mechanical noise apparent velocity corresponding to the second seismic trace dataset is picked under the new observation system described above, for example, 3500 m / s.

[0072] Figure 5 The diagram schematically illustrates (a) the result of dynamic correction processing of mechanical interference waves on a second seismic trace dataset under the new observation system described above, according to an embodiment of this disclosure; (b) the result of tilt angle filtering and denoising processing of the low-angle reflection phase axis of the seismic trace after dynamic correction; and (c) the result obtained by further performing reaction correction processing. Figure 5 In (a) to (c), the green line is used to indicate the shot-receiver distance line.

[0073] Using the apparent velocity of the aforementioned mechanical noise as the single-shot dynamic correction velocity, dynamic correction processing was performed on the aforementioned second seismic trace dataset. The processed results are referenced... Figure 5 As shown in (a), mechanical noise interference is basically flattened and has a low tilt angle feature (other effective information angles become tilted).

[0074] In some embodiments, the apparent tilt angle of the dynamically corrected seismic trace can be read via an interactive tool in the electronic device.

[0075] Based on Fourier transform, tilt angle filtering is performed on low-angle reflection in-phase axes (mechanical noise interference). The processed result is referenced. Figure 5 As shown in (b), the suppressed seismic data contains virtually no mechanical interference noise.

[0076] In step S140, the above-mentioned third seismic trace dataset is subjected to reaction correction processing, and the processing result is subjected to observation system restoration processing to obtain the fourth seismic trace dataset corresponding to the original observation system after noise suppression.

[0077] Reverse correction is the inverse process of dynamic correction, used to restore the dynamically corrected gather data to its original shot-receiver distance dependent state (i.e., reconstruct the hyperbolic shape). The result after reverse correction is referenced... Figure 5 As shown in (c).

[0078] In addition, the processing results were restored using the original observation system to obtain the fourth seismic trace dataset after noise suppression.

[0079] In some embodiments, in addition to steps S110 to S140, the above method further includes: merging the fourth seismic trace dataset with the fifth seismic trace dataset that has been selected from the seismic data and is not affected by mechanical interference source noise, to obtain the target seismic single-shot dataset.

[0080] Figure 6AThe diagram illustrates the results of a mechanical noise processing scheme based on conventional methods. Figure 6B The diagram illustrates the result of seismic data processing based on the mechanical interference noise suppression method provided in the embodiments of this disclosure.

[0081] Reference Figure 6A As shown, in conventional processing methods, the original data is subjected to regulated noise suppression using the frequency-velocity method in both the single-shot domain and the receiver domain, and abnormal amplitudes are suppressed using statistical principles. Although the signal-to-noise ratio can be improved to some extent, mechanical interference is a stubborn noise that does not satisfy either linear laws or statistical noise suppression conditions. Conventional denoising processes have not suppressed this group of noise. (See details...) Figure 6A The noise area indicated by the middle arrow.

[0082] In comparison, refer to Figure 6B As shown, after mechanical noise processing based on the scheme provided in this embodiment, the fourth seismic trace dataset corresponding to the original observation system after noise suppression is merged with the fifth seismic trace dataset selected from the seismic data that is not affected by mechanical interference source noise. (Refer to...) Figure 6B As shown by the arrow, the obtained target seismic single-shot dataset effectively suppresses mechanical interference noise and does not contain any noise regions. Therefore, the above scheme can improve the signal-to-noise ratio of the processing results, enhance target denoising without harming other seismic data channels, has a fast seismic data processing efficiency, and saves processing resources.

[0083] In summary, the mechanical interference noise suppression method provided in this embodiment enhances target denoising without harming other seismic data traces by filtering the first seismic trace dataset affected by mechanical interference noise sources, i.e., identifying seismic data segments affected by mechanical noise. Furthermore, by redefining the observation system and generating a second seismic trace dataset under the new observation system, the seismic traces contaminated by mechanical noise have a virtual shot-receiver distance relationship, enabling subsequent dynamic correction and tilt angle filtering denoising. This scheme effectively removes mechanical noise without losing useful components of other seismic data. Moreover, it suppresses noise within a single shot domain, reducing data domain switching, significantly lowering processing time, and saving disk space. Overall, the above scheme improves the signal-to-noise ratio of the processing results, enhances target denoising without harming other seismic data traces, has fast seismic data processing efficiency, and saves processing resources.

[0084] A second exemplary embodiment of this disclosure provides an apparatus for suppressing mechanical interference noise.

[0085] The aforementioned device for suppressing mechanical interference noise includes: a screening module, an observation system conversion module, a noise reduction processing module, and an inverse conversion module.

[0086] The aforementioned filtering module is used to filter the first seismic trace dataset that is affected by noise from mechanical interference sources in the seismic data.

[0087] The aforementioned observation system conversion module is used to redefine the observation system in the aforementioned first seismic trace dataset by using the first target seismic trace closest to the mechanical interference source as the minimum offset, and generate a second seismic trace dataset under the new observation system.

[0088] The aforementioned denoising module is used to perform dynamic correction processing of mechanical interference waves and tilt angle filtering denoising processing on the second seismic trace dataset under the new observation system to obtain the third seismic trace dataset.

[0089] The aforementioned inverse conversion module is used to perform reaction correction processing on the aforementioned third seismic trace dataset, and to perform observation system restoration processing on the processing result to obtain the fourth seismic trace dataset corresponding to the original observation system after noise suppression.

[0090] In some embodiments, the above apparatus further includes a merging processing module.

[0091] The aforementioned merging module is used to merge the fourth seismic trace dataset with the fifth seismic trace dataset, which has been filtered out from the seismic data and is not affected by mechanical interference noise, to obtain the target seismic single-shot dataset.

[0092] In some embodiments, the above-mentioned filtering module includes: an interference source localization submodule, an influence range determination submodule, and a filtering submodule.

[0093] The aforementioned interference source location submodule is used to determine the location information of mechanical interference sources based on actual exploration information.

[0094] The aforementioned influence range determination submodule is used to determine the influence range of the aforementioned mechanical interference source based on noise measurement records.

[0095] The aforementioned filtering submodule is used to filter the first seismic trace dataset affected by noise from the mechanical interference source in the seismic data based on the location information of the mechanical interference source and the influence range.

[0096] The noise measurement records are obtained in the following way: before or during the actual exploration, detection equipment is deployed at multiple key points in the expected impact area; based on the background vibration signals recorded by the detection equipment when the mechanical noise is turned on and off, noise measurement records are obtained, and the background vibration signals are used to indicate the ground vibration signals when the detection equipment is turned on and off.

[0097] In some embodiments, determining the influence range of the mechanical interference source based on noise measurement records includes: comparing the spectral differences when the noise is on and off based on the background vibration signal to identify the target frequency component corresponding to the mechanical noise; calculating the noise amplitude or energy of the mechanical noise at different distances based on the target frequency component, and plotting the attenuation curve of the noise amplitude or energy as a function of distance; and comparing the attenuation curve with a set signal-to-noise ratio threshold to determine the distance range where the noise amplitude is lower than the signal-to-noise ratio threshold as the influence range of the mechanical interference source.

[0098] In some embodiments, the above-mentioned observation system conversion module includes: a center positioning submodule, a shot-receiver distance conversion submodule, and a new system data determination submodule.

[0099] The aforementioned center positioning submodule is used to take the first target seismic trace closest to the mechanical interference source as the minimum offset position.

[0100] The aforementioned shot-receiver offset conversion submodule is used to determine the virtual shot-receiver offset corresponding to each first seismic trace for each location other than the aforementioned first target seismic trace, based on the difference between the station number of each first seismic trace and the station number of the aforementioned first target seismic trace; wherein, the distance between traces is the same as the original receiver interval distance.

[0101] The aforementioned new system data determination submodule is used to construct the first target seismic trace and the first seismic trace represented by virtual seismic trace shot-receiver distance into a second seismic trace dataset under the new observation system.

[0102] In some embodiments, the denoising processing module includes: a visual speed determination submodule, a dynamic correction processing submodule, and a tilt angle filtering submodule.

[0103] The aforementioned apparent velocity determination submodule is used to determine the mechanical noise apparent velocity corresponding to the second seismic trace dataset under the new observation system.

[0104] The aforementioned dynamic correction processing submodule is used to perform dynamic correction processing on the aforementioned second seismic trace dataset by taking the apparent velocity of the mechanical noise as the single-shot dynamic correction velocity; the processed seismic trace has low tilt angle characteristics.

[0105] The aforementioned tilt angle filtering submodule is used to perform tilt angle filtering and noise reduction processing on the low-angle reflection phase axis of the dynamically corrected seismic trace based on Fourier transform, to obtain the third seismic trace dataset.

[0106] In some embodiments, determining the apparent velocity of mechanical noise corresponding to the second seismic trace dataset under the new observation system includes: picking a clear and continuous noise in-phase axis segment in the second seismic trace dataset under the new observation system; and calculating the apparent velocity of mechanical noise based on the spatial distance difference and time difference corresponding to the picked noise in-phase axis segment.

[0107] The mechanical interference noise suppression device provided in this embodiment enhances target denoising without harming other seismic data channels by filtering out seismic data segments affected by mechanical noise. Furthermore, by redefining the observation system and generating a second seismic trace dataset under the new system, the seismic traces contaminated by mechanical noise have a virtual shot-receiver distance relationship, enabling subsequent dynamic correction and tilt angle filtering denoising. This scheme effectively removes mechanical noise without losing useful components of other seismic data. Moreover, it suppresses noise within a single shot domain, reducing data domain switching, significantly lowering processing time, and saving disk space. Overall, the above scheme improves the signal-to-noise ratio of the processing results, enhances target denoising without harming other seismic data channels, has fast seismic data processing efficiency, and saves processing resources.

[0108] For more details of this embodiment, please refer to the relevant description of the first embodiment, which will not be repeated here.

[0109] Any number of the functional modules included in the aforementioned mechanical interference noise suppression device can be combined into one module, or any one of the modules can be split into multiple modules. Alternatively, at least part of the functionality of one or more of these modules can be combined with at least part of the functionality of other modules and implemented in one module. At least one of the functional modules included in the aforementioned mechanical interference noise suppression device can be at least partially implemented as hardware circuitry, such as a field-programmable gate array (FPGA), a programmable logic array (PLA), a system-on-a-chip, a system-on-a-substrate, a system-on-package, an application-specific integrated circuit (ASIC), or any other reasonable means of integrating or packaging the circuitry, or implemented in software, hardware, or firmware, or in any appropriate combination of any of these three implementation methods. Alternatively, at least one of the functional modules included in the aforementioned mechanical interference noise suppression device can be at least partially implemented as a computer program module, which, when run, can perform corresponding functions.

[0110] A third exemplary embodiment of this disclosure provides an electronic device.

[0111] Figure 7 The schematic diagram illustrates a structural block diagram of an electronic device provided in an embodiment of the present disclosure.

[0112] Reference Figure 7 As shown, the electronic device 700 provided in this embodiment includes a processor 701, a communication interface 702, a memory 703, and a communication bus 704. The processor 701, the communication interface 702, and the memory 703 communicate with each other through the communication bus 704. The memory 703 is used to store computer programs. When the processor 701 executes the program stored in the memory, it implements the mechanical interference noise suppression method described above.

[0113] A fourth exemplary embodiment of this disclosure also provides a computer-readable storage medium. The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method for suppressing mechanical interference noise as described above.

[0114] The computer-readable storage medium may be included in the device or apparatus described in the above embodiments; or it may exist independently and not assembled into the device or apparatus. The computer-readable storage medium carries one or more programs that, when executed, implement the method according to the embodiments of this disclosure.

[0115] According to embodiments of this disclosure, the computer-readable storage medium can be a non-volatile computer-readable storage medium, such as including, but not limited to: portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof. In this disclosure, the computer-readable storage medium can be any tangible medium that contains or stores a program that can be used by or in conjunction with an instruction execution system, apparatus, or device.

[0116] It should be noted that, in this document, relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, 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, article, or apparatus. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element.

[0117] The above description is merely a specific embodiment of this disclosure, enabling those skilled in the art to understand or implement it. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of this disclosure. Therefore, this disclosure is not to be limited to the embodiments shown herein, but is to be accorded the widest scope consistent with the principles and novel features claimed herein.

Claims

1. A method for suppressing mechanical interference noise, characterized in that, include: Filter the first seismic trace dataset that is affected by noise from mechanical interference sources in the seismic data; In the first seismic trace dataset, the observation system is redefined with the first target seismic trace closest to the mechanical interference source as the minimum offset, and a second seismic trace dataset under the new observation system is generated. The mechanical interference wave was dynamically corrected and the tilt angle was filtered and denoised for the second seismic trace dataset under the new observation system to obtain the third seismic trace dataset. The third seismic trace dataset is subjected to reaction correction processing, and the processing result is used for observation system restoration processing to obtain the fourth seismic trace dataset corresponding to the original observation system after noise suppression.

2. The method according to claim 1, characterized in that, The first seismic trace dataset affected by mechanical interference noise sources was filtered from the seismic data, including: Based on actual exploration information, the location information of the mechanical interference source was determined; Based on the noise measurement records, the influence range of the mechanical interference source was determined; Based on the location information of the mechanical interference source and the range of influence, the first seismic trace dataset affected by the noise from the mechanical interference source is selected from the seismic data; The noise measurement records are obtained by: deploying detection equipment at multiple key points in the expected influence area before or during the actual exploration; obtaining noise measurement records based on the background vibration signals recorded by the detection equipment when the mechanical noise is turned on and off, wherein the background vibration signals are used to indicate the ground vibration signals when the detection equipment is turned on and off.

3. The method according to claim 2, characterized in that, The step of determining the influence range of the mechanical interference source based on noise measurement records includes: Based on the background vibration signal, compare the spectral differences when the noise is on and off, and identify the target frequency components corresponding to the mechanical noise; Based on the target frequency components, calculate the noise amplitude or energy of the mechanical noise at different distances, and plot the attenuation curve of the noise amplitude or energy as a function of distance. By comparing the attenuation curve with the set signal-to-noise ratio threshold, the distance range corresponding to the noise amplitude being lower than the signal-to-noise ratio threshold is determined as the influence range of the mechanical interference source.

4. The method according to claim 1, characterized in that, The observation system is redefined using the first target seismic trace closest to the source of mechanical interference as the minimum offset, generating a second seismic trace dataset under the new observation system, including: The first target seismic trace closest to the mechanical interference source is taken as the minimum offset position; For each first seismic trace at a location other than the first target seismic trace, the virtual seismic trace shot-receiver distance corresponding to each first seismic trace is determined based on the difference between the station number of each first seismic trace and the station number of the first target seismic trace; wherein, the distance between traces is the same as the original receiver interval distance; The first target seismic trace and the first seismic trace represented by virtual seismic trace shot-receiver distance are constructed into a second seismic trace dataset under the new observation system.

5. The method according to any one of claims 1-4, characterized in that, Dynamic correction processing for mechanical interference waves and tilt angle filtering denoising processing are performed on the second seismic trace dataset under the new observation system to obtain the third seismic trace dataset, which includes: Determine the apparent velocity of the mechanical noise corresponding to the second seismic trace dataset under the new observation system; The apparent velocity of mechanical noise is used as the single-shot dynamic correction velocity to perform dynamic correction processing on the second seismic trace dataset; the processed seismic trace has low tilt angle characteristics. Based on Fourier transform, the low-angle reflection phase axis of the seismic trace after dynamic correction is subjected to tilt angle filtering for noise reduction to obtain the third seismic trace dataset.

6. The method according to claim 5, characterized in that, Determining the apparent mechanical noise velocity corresponding to the second seismic trace dataset under the new observation system includes: Pick a clear and continuous noisy in-phase axis segment from the second seismic trace dataset under the new observation system; The apparent velocity of mechanical noise is calculated based on the spatial distance difference and time difference corresponding to the picked-up noise in-phase axis segments.

7. The method according to any one of claims 1-4 and 6, characterized in that, Also includes: The fourth seismic trace dataset is merged with the fifth seismic trace dataset, which is selected from the seismic data and is not affected by mechanical interference noise, to obtain the target seismic single-shot dataset.

8. A device for suppressing mechanical interference noise, characterized in that, include: The filtering module is used to filter the first seismic trace dataset that is affected by noise from mechanical interference sources in the seismic data; The observation system conversion module is used to redefine the observation system in the first seismic trace dataset by taking the first target seismic trace closest to the mechanical interference source as the minimum offset, and generate a second seismic trace dataset under the new observation system. The denoising module is used to perform dynamic correction processing of mechanical interference waves and tilt angle filtering denoising processing on the second seismic trace dataset under the new observation system to obtain the third seismic trace dataset. The inverse conversion module is used to perform reaction correction processing on the third seismic trace dataset and then perform observation system restoration processing on the processing result to obtain the fourth seismic trace dataset after noise suppression corresponding to the original observation system.

9. An electronic device, characterized in that, It includes a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; Memory, used to store computer programs; A processor, when executing a program stored in memory, implements the method of any one of claims 1-7.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by a processor, it implements the method of any one of claims 1-7.

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