Data-driven directional signal deconvolution method, device and readable storage medium

Abstract

The present invention provides a data-driven directional signal deconvolution method, device, and readable storage medium, belonging to the field of seismic data processing technology. The method comprises: obtaining a pre-stack seismic trace gather and a preset expected wavelet; performing a Fourier forward transform, a three-dimensional transform, and an inverse Fourier transform on the pre-stack seismic trace gather to obtain first seismic data; performing a time difference correction on the first seismic data to obtain second seismic data; projecting the first seismic data and the second seismic data onto a preset bin grid to form first directional seismic data and second directional seismic data; obtaining a directional matching operator based on the first directional seismic data and the preset expected wavelet; correcting the second directional seismic data using the directional matching operator, and performing a three-dimensional inverse transform on the corrected data to obtain final seismic trace gather data. The present invention has the advantages of high computational accuracy and efficiency, significantly reducing memory usage and computational cost, and improving the signal-to-noise ratio of seismic data.

Description

Technical Field

[0001] The present invention relates to the technical field of seismic data processing, and in particular to a data-driven directional signal deconvolution method, a data-driven directional signal deconvolution device and a readable storage medium. Background Art

[0002] During marine oil and gas exploration, airguns are often used as excitation sources due to limited sea surface excitation conditions to minimize damage to the marine environment and provide stable excitation energy. However, as the depth of the seabed and the depth of the target underground layer increase, the seismic signal emitted by a single airgun loses its energy. As a result, the signal reflected from the underground, received by the geophone, is easily obscured by the bubble response formed by the transient pulse, making it difficult to obtain satisfactory seismic data. To increase the excitation source energy and improve the energy proportion of the effective signal, an airgun array is often used as the excitation source in actual marine seismic acquisition.

[0003] An airgun array arrangement involves arranging multiple single airguns in a specific spatial configuration (including both horizontal and vertical arrangements). The signals emitted by each airgun are then synthesized into a primary excitation wavelet signal based on the airgun's spatial position. While this array arrangement effectively enhances excitation energy, because the spatial center of the combination no longer satisfies the assumption of point source excitation, the superposition response of the signals emitted by each airgun varies at different angles. Ultimately, the synthesized far-field wavelet varies with the superposition angle, exhibiting significant directional dependence. In marine seismic data processing, to improve data quality, it is crucial to extract seismic wavelets with a high signal-to-noise ratio and stable morphology. However, directional effects, which disrupt the lateral consistency of the wavelets, must be eliminated. Historically, marine seismic exploration has primarily relied on streamer acquisition, which only yields narrow-azimuth seismic data. The directional effects generated by the superposition of far-field wavelets at different angles are less pronounced. One-dimensional signal deconvolution can effectively address this issue. In addition, in recent years, with the development of ocean OBN (Ocean Bottom Nodes) acquisition technology, it has become popular because it can provide all-round, high-density, long-offset data information, which is more helpful to improve the quality of seismic imaging of complex oil and gas reservoirs. However, it also poses more severe challenges to the processing of OBN data. Among them, the directional effect of far-field wavelets has become extremely prominent. In order to solve this problem, three technical difficulties are faced: (1) How to characterize the directionality of far-field wavelets; (2) How to extract far-field wavelets with directions; (3) How to eliminate the directional effect of far-field wavelets. In view of the above three technical difficulties, a method and device that can effectively eliminate the directional effect of far-field wavelets is urgently needed. Summary of the Invention

[0004] The purpose of the embodiments of the present invention is to provide a data-driven directional signal deconvolution method, device and readable storage medium to at least solve the problems in the above-mentioned prior art, that is, the directional effect of the far-field wavelet is extremely prominent, the directionality of the far-field wavelet cannot be characterized, the far-field wavelet with direction cannot be extracted; and the directional effect of the far-field wavelet cannot be eliminated.

[0005] In order to achieve the above object, the present invention provides a data-driven direction signal deconvolution method in a first aspect, the method comprising:

[0006] Obtain pre-stack seismic gather data and preset expected wavelets during seismic data acquisition;

[0007] The pre-stack seismic gather data are sequentially subjected to Fourier forward transform, three-dimensional transform and inverse Fourier transform to obtain first seismic data;

[0008] Performing time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data;

[0009] Projecting the azimuth of each seismic trace in the second seismic data onto a preset bin grid, determining a seismic trace in each bin, and forming first directional seismic data based on the seismic traces of all bins;

[0010] Projecting the azimuth of each seismic trace in the first seismic data onto a preset bin grid and determining a seismic trace in each bin, and forming second directional seismic data based on the seismic traces of all bins;

[0011] Obtaining a direction matching operator based on the first directional seismic data and the preset expected wavelet;

[0012] The second directional seismic data is corrected by using the direction matching operator, and the corrected data is subjected to three-dimensional Perform inverse transformation to obtain the final seismic gather data.

[0013] Optionally, the pre-stack seismic gather data is subjected to Fourier forward transform, three-dimensional Transformation and inverse Fourier transformation are performed to obtain the first seismic data, including:

[0014] Based on the shot point coordinates and receiver point coordinates of pre-stack seismic gather data, the offset of each seismic trace is calculated;

[0015] Performing a Fourier forward transform on the pre-stack seismic gather data along a time direction to obtain first seismic sub-data;

[0016] Based on the offset of each seismic trace, the conjugate operator of the horizontal transformation operator and the vertical transformation operator is obtained;

[0017] The seismic sub-data are subjected to three-dimensional conjugation based on the conjugate operator. Forward transformation to obtain the second seismic sub-data;

[0018] Perform an inverse Fourier transform on the second seismic sub-data along the time direction to obtain the first seismic data.

[0019] Optionally, the expression of the conjugate operator of the transverse transformation operator is:

[0020] ;

[0021] in, is the conjugate operator of the transverse transformation operator; is the circular frequency of the seismic data; for x Offset in direction; m is the number of horizontal seismic traces; is the transverse ray parameter; k for The number of channels in the horizontal direction of the domain;

[0022] The expression of the conjugate operator of the longitudinal transformation operator is:

[0023] ;

[0024] in, is the conjugate operator of the transverse transformation operator; is the circular frequency of the seismic data; for y Offset in direction; n is the number of horizontal seismic traces; is the transverse ray parameter; j for The number of lanes in the vertical direction of the domain.

[0025] Optionally, performing time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data includes:

[0026] The following formula is used for time difference correction:

[0027] ;

[0028] in, is the second earthquake data; is the first earthquake data; is the intercept time at zero offset, is the layer velocity of the first medium; and is the ray parameter of each seismic trace in the first seismic data; The distance from the calibration plane to the water surface.

[0029] Optionally, the azimuth angle includes a horizontal azimuth angle and a vertical emission angle, and the method further includes:

[0030] The horizontal azimuth angle and vertical emission angle are calculated using the following formula:

[0031] ;

[0032] ;

[0033] in, is the horizontal azimuth; is the vertical exit angle; and is the ray parameter of each seismic trace; is the layer velocity of the first medium.

[0034] Optionally, obtaining a direction matching operator based on the first directional seismic data and the preset expected wavelet includes:

[0035] Performing wavelet matching on the first directional seismic data and the preset expected wavelet to obtain a matching operator;

[0036] Based on the matching operator, a direction matching operator is obtained using a least squares criterion.

[0037] Optionally, obtaining a direction matching operator based on the first directional seismic data and the preset expected wavelet further includes:

[0038] The direction matching operator is obtained using the following formula:

[0039] ;

[0040] ;

[0041] in, is the direction matching operator; is the first directional seismic data; is the preset expected wavelet.

[0042] Optionally, the second directional seismic data is corrected using the direction matching operator, and the corrected data is subjected to three-dimensional Inverse transformation is performed to obtain the final seismic gather data, including:

[0043] The final seismic gather data is obtained using the following formula:

[0044] ;

[0045] in, is the final seismic gather data; is the horizontal operator; is the second directional seismic data; is the direction matching operator; is the vertical operator.

[0046] A second aspect of the present invention provides a data-driven directional signal deconvolution device, the device comprising:

[0047] A data acquisition module, used to obtain pre-stack seismic gather data and preset expected wavelets during seismic data acquisition;

[0048] The data transformation module is used to sequentially perform Fourier forward transformation, three-dimensional transform and inverse Fourier transform to obtain first seismic data;

[0049] a time difference correction module, configured to perform time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data;

[0050] a first determining module, configured to project the azimuth of each seismic trace in the second seismic data onto a preset bin grid, determine a seismic trace in each bin, and form first directional seismic data based on the seismic traces of all bins;

[0051] A second determining module is configured to project the azimuth of each seismic trace in the first seismic data onto a preset bin grid and determine a seismic trace in each bin, and form second directional seismic data based on the seismic traces of all bins;

[0052] An operator determination module, configured to obtain a direction matching operator based on the first directional seismic data and the preset expected wavelet;

[0053] A data output module is used to modify the second directional seismic data using the direction matching operator and perform three-dimensional transformation on the modified data. Perform inverse transformation to obtain the final seismic gather data.

[0054] On the other hand, the present invention further provides a readable storage medium having instructions stored thereon, wherein the instructions are used to enable a machine to execute the above-mentioned data-driven directional signal deconvolution method.

[0055] This technical solution does not require known prior information or interference from human factors during the seismic data processing process, thus avoiding the problem of low-frequency signals in the time and space domain of seismic data not converging as the offset distance increases. It has high calculation accuracy and is easy to implement, improves the signal-to-noise ratio of seismic data, significantly reduces memory usage and computing costs, and is suitable for processing large amounts of seismic data.

[0056] Other features and advantages of the embodiments of the present invention will be described in detail in the subsequent detailed description. BRIEF DESCRIPTION OF THE DRAWINGS

[0057] The accompanying drawings are used to provide a further understanding of the embodiments of the present invention and constitute a part of the specification. Together with the following detailed description, they are used to explain the embodiments of the present invention, but do not constitute a limitation of the embodiments of the present invention. In the accompanying drawings:

[0058] Figure 1 is a flow chart of the data-driven direction signal deconvolution method provided by the present invention;

[0059] Figure 2 Schematic diagram of the common receiver gather of marine OBN seismic data provided by the present invention;

[0060] Figure 3 It is a schematic diagram of the preset expected wavelet of the source acquisition design provided by the present invention;

[0061] Figure 4 The present invention provides a common detection point gather transformation to three-dimensional τ- p Schematic diagram of domain seismic data;

[0062] Figure 5 The present invention provides a three-dimensional τ- p Schematic diagram of the first arrival correction of the domain seismic data;

[0063] Figure 6 The present invention provides a three-dimensional τ- p Schematic diagram of horizontal azimuth information extracted from the domain;

[0064] Figure 7 The present invention provides a three-dimensional τ- p Schematic diagram of vertical emission angle information extracted from the domain;

[0065] Figure 8 The present invention provides a three-dimensional τ- p Schematic diagram showing the display results of projecting the data onto the angle bin after domain first arrival correction;

[0066] Figure 9 The present invention provides a three-dimensional τ- p Schematic diagram of extracting directional far-field wavelets from the domain;

[0067] Figure 10 Schematic diagram of the operator after the far-field wavelet provided by the present invention is matched with the expected wavelet;

[0068] Figure 11 The present invention provides a three-dimensional τ- p Schematic diagram of the application of domain matching operator;

[0069] Figure 12 is the three-dimensional τ- p Schematic diagram of the inverse transformed data;

[0070] Figure 13 Schematic diagram of seismic wavelet spectrum data with directional effect eliminated provided by the present invention;

[0071] Figure 14 It is a structural schematic diagram of the data-driven direction signal deconvolution device provided by the present invention.

[0072] Description of Reference Numerals

[0073] 10-data acquisition module; 20-data conversion module; 30-time difference correction module;

[0074] 40-first determination module; 50-second determination module; 60-operator determination module;

[0075] 70-Data output module. DETAILED DESCRIPTION

[0076] The following describes the specific embodiments of the present invention in detail with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are only used to illustrate and explain the present invention and are not intended to limit the present invention.

[0077] Figure 1 is a flow chart of the data-driven direction signal deconvolution method provided by the present invention; Figure 2 Schematic diagram of the common receiver gather of marine OBN seismic data provided by the present invention; Figure 3 It is a schematic diagram of the preset expected wavelet of the source acquisition design provided by the present invention; Figure 4 The present invention provides a common detection point gather to transform into three-dimensional Schematic diagram of domain seismic data; Figure 5 The present invention provides a three-dimensional Schematic diagram of the first arrival correction of the domain seismic data; Figure 6 The present invention provides a three-dimensional Schematic diagram of horizontal azimuth information extracted from the domain; Figure 7 The present invention provides a three-dimensional Schematic diagram of vertical emission angle information extracted from the domain; Figure 8The present invention provides a three-dimensional Schematic diagram showing the display results of projecting the data onto the angle bin after domain first arrival correction; Figure 9 The present invention provides a three-dimensional Schematic diagram of extracting directional far-field wavelets from the domain; Figure 10 Schematic diagram of the operator after the far-field wavelet provided by the present invention is matched with the expected wavelet; Figure 11 The present invention provides a three-dimensional Schematic diagram of the application of domain matching operator; Figure 12 It is the three-dimensional after the operator provided by the present invention is applied Schematic diagram of the inverse transformed data; Figure 13 Schematic diagram of seismic wavelet spectrum data with directional effect eliminated provided by the present invention; Figure 14 It is a structural schematic diagram of the data-driven direction signal deconvolution device provided by the present invention.

[0078] like Figure 1 As shown, an embodiment of the present invention provides a data-driven directional signal deconvolution method, the method comprising:

[0079] Step 1: Obtain pre-stack seismic gather data and preset expected wavelets during seismic data acquisition;

[0080] Specifically, in this example, the known pre-stack seismic gathers and the preset expected wavelet of source acquisition design As input data, and are the horizontal and vertical coordinates within the seismic acquisition area, is the travel time coordinate of the seismic wave propagation. Figure 2 The input pre-stack common detector point gathers are shown as follows Figure 3 The desired wavelet of the acquisition design shown;

[0081] Step 2: Perform Fourier forward transform, three-dimensional transform and inverse Fourier transform to obtain first seismic data;

[0082] Specifically include: based on pre-stack seismic gathers The shot point coordinates in ) and the coordinates of the detection points ( ), among which, prestack seismic gathers For a common receiver gather (the receiver coordinates of each gather are the same, but the shot coordinates are different), calculate the distance from the receiver point to each shot point, called the shot offset, and use vector and express.

[0083] Seismic Gathers Each trace in the time direction is transformed by fast Fourier transform, and the time-space domain data is transformed into the frequency-space domain, and the seismic data is obtained as , that is, as the first seismic sub-data, where, is the circular frequency of the seismic data, given by Calculated, The acquisition frequency of seismic data is a known parameter.

[0084] Seismic data Three-dimensional Transformation, first, using the vector offset of each channel in step 2) and , build three-dimensional The horizontal transformation operator and the vertical transformation operator of the transformation are expressed as:

[0085] (1)

[0086] (2)

[0087] In formula (1), is the lateral transformation operator; is the circular frequency of the seismic data, m is the number of horizontal seismic traces, is the transverse ray parameter (slope), k for The number of channels in the horizontal direction of the domain. Similarly, in formula (2), is the longitudinal transformation operator; is the circular frequency of the seismic data, n is the number of longitudinal seismic traces, is the longitudinal ray parameter, j for The number of lanes in the vertical direction of the domain.

[0088] The three-dimensional shape of each channel can be calculated by formula (1) and (2). Conjugate operator of transformation operator 、 ,The calculation formulas are as follows (3) and (4);

[0089] (3)

[0090] (4)

[0091] in, is the conjugate operator of the transverse transformation operator; is the circular frequency of the seismic data; for x Offset in direction;m is the number of horizontal seismic traces; is the transverse ray parameter; k for The number of channels in the horizontal direction of the domain; is the conjugate operator of the transverse transformation operator; is the circular frequency of the seismic data; for y Offset in direction; n is the number of horizontal seismic traces; is the transverse ray parameter; j for The number of lanes in the vertical direction of the domain.

[0092] Using the conjugate operator of each seismic trace obtained above, the seismic data Three-dimensional The forward transformation process is to transform from the frequency-space domain to the frequency-slowness domain, i.e. the second seismic sub-data, which can be expressed by the following formula:

[0093] (5)

[0094] Among them, in formula (5), For three-dimensional The seismic data volume after positive transformation (the second seismic sub-data) is , perform fast inverse Fourier transform along the time direction to obtain three-dimensional Spectral data of the domain , i.e. the first seismic data; Figure 4 As shown, the input pre-stack gather ( Figure 2 ) Transformed to three dimensions The spectral data of the domain are displayed.

[0095] Step 3: performing time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data;

[0096] Specifically, the three-dimensional Seismic data in the domain Perform the first arrival coaxial correction. Using the flattened coaxial axis, the expansion process of the bubble energy can be identified. The correction time difference formula for each data is:

[0097] (6)

[0098] In formula (6), is the time difference of each track, is the intercept time at zero offset, is the layer velocity of the first medium, generally the water velocity is 1500m / s, To correct the distance from the plane to the water surface, the correction plane is an artificially defined horizontal plane, which is a constant. All traces in the image are corrected to this plane to obtain the corrected seismic data. , that is, the initial arrival co-axial correction process is realized. Figure 5 For three-dimensional spectral data of the domain ( Figure 4 ) After the initial arrival correction to the horizontal plane, it can be seen that the reverse arc axis is effectively flattened, and the low-frequency bubble expansion process is easily identified (the position marked by the arrow in the figure).

[0099] (7)

[0100] The final transformation is:

[0101] ;

[0102] in, is the second earthquake data; is the first earthquake data; is the intercept time at zero offset, is the layer velocity of the first medium, generally the water velocity is 1500m / s; and is the ray parameter of each seismic trace in the first seismic data; To correct the distance from the plane to the water surface;

[0103] Step 4: Projecting the azimuth of each seismic trace in the second seismic data onto a preset bin grid, determining a seismic trace in each bin, and forming first directional seismic data based on the seismic traces of all bins;

[0104] For the first arrival corrected seismic data in the above steps , that is, the ray parameter of each seismic trace in the second seismic data and Calculate the horizontal azimuth , Figure 6 It is the azimuth information extracted from the seismic data after first arrival correction (same departure angle, different azimuth display).

[0105] (8)

[0106] Similarly, according to the ray parameters of each seismic trace 、 , and the layer velocity of the first medium , generally the water speed is 1500m / s, calculate the vertical angle of each channel , Figure 7It is the exit angle information extracted from the seismic data after first arrival correction (the same azimuth, different exit angles are displayed).

[0107] (9)

[0108] The range of azimuth angle and emission angle of formula (8) and formula (9) is [0°~90°]. and the exit angle , according to 1° 1° method to perform surface element meshing.

[0109] Seismic data The azimuth and exit angle of each trace in the image are projected onto the corresponding bin grid defined in the above steps, and the seismic data are rearranged to obtain new seismic data with angle information. ;like Figure 8 As shown in FIG, the display result of projecting seismic data onto angle bins is shown, and the phase of the first arrival information in each bin is the same.

[0110] Since the azimuth and take-off angles of the seismic traces in each bin are very small and the first arrival signals have been leveled, the same-phase superposition can be achieved to enhance the effective signal. All traces in each bin are superimposed to obtain a unique seismic trace in each bin. In this way, the seismic data in all bins are superimposed to form a directional seismic data, which is the directional far-field wavelet. , i.e. the first directional seismic data; Figure 9 The directional far-field wavelet data within each bin are obtained by superimposing the seismic traces within the bin.

[0111] Step 5: Projecting the azimuth of each seismic trace in the first seismic data onto a preset bin grid and determining a seismic trace in each bin, and forming second directional seismic data based on the seismic traces of all bins;

[0112] Specifically, for earthquake data that have not been leveled , that is, the first seismic data is also divided into the same surface element grid using the same method to obtain the new seismic data , i.e., the second directional seismic data. The specific method is the same as the steps of projecting the azimuth of each seismic trace in the second seismic data onto a preset bin grid, determining a seismic trace in each bin, and forming the first directional seismic data based on the seismic traces of all bins, and will not be repeated here.

[0113] Step 6: obtaining a direction matching operator based on the first directional seismic data and the preset expected wavelet;

[0114] Specifically, using the obtained preset expected wavelet and the obtained directional far-field wavelet , i.e., the first directional seismic data, performs wavelet matching to obtain a matching operator; Figure 10 The matching operator displayed results are obtained by wavelet matching. The specific calculation formula is as follows.

[0115] (10)

[0116] Then, using the least squares criterion, we can find the direction matching operator from formula (10): , the calculation formula is as follows:

[0117] (11)

[0118] in, is the direction matching operator; is the first directional seismic data; is the preset expected wavelet.

[0119] Step 7: Use the direction matching operator to correct the second directional seismic data, and perform three-dimensional Perform inverse transformation to obtain the final seismic gather data.

[0120] The direction matching operator determined in formula (11) ,like Figure 11 The direction matching operator shown is applied to the seismic data Above, that is, the second directional seismic data, is as follows:

[0121] (12)

[0122] Seismic data The lateral operator calculated above is and longitudinal operator Interaction, resulting in three-dimensional Inverse transformed seismic data , which is the time-space domain seismic data after the directional signal deconvolution is applied, as the final seismic gather data, the inverse transformation formula is as follows;

[0123] (13)

[0124] After fusion, we get the final formula:

[0125]

[0126] in, is the final seismic gather data; is the horizontal operator; is the second directional seismic data; is the direction matching operator; is the vertical operator.

[0127] like Figure 12 The comparison results of seismic data before and after the application of directional signal deconvolution are shown in the figure. The arrows mark the positions where low-frequency interference is effectively eliminated, and the lateral consistency of the seismic wavelet is more continuous and reliable. Figure 12 In the figure, the left image is a schematic diagram before the application of the directional signal deconvolution technology, and the right image is a schematic diagram after the application of the directional signal deconvolution technology; Figure 13 As shown in the figure, Data1 (black line) is a schematic diagram of the spectrum analysis of seismic data before the application of directional signal deconvolution, and Data2 (gray line) is a schematic diagram of the spectrum analysis of seismic data after the application of directional signal deconvolution. After the directionality of the far-field wavelet is eliminated, the spectrum of the seismic data is effectively expanded and the resolution is significantly improved.

[0128] Through the above-mentioned processing steps, the data-driven directional signal deconvolution process is completed, and the problem of seismic wavelet directionality introduced by the combination of exciting sources is eliminated. And for the processing of marine OBN wide-azimuth seismic data, this solution proposes a method for eliminating the directional effect of far-field wavelets. Due to the different spatial arrangement positions of the various guns in the air gun array, the signal excited by each gun, in the process of superposition to form far-field wavelets, obviously shows a directional effect. This easily causes the lateral consistency of the wavelets to deteriorate, seriously affecting the quality of seismic data. The present application can effectively eliminate the directionality of far-field wavelets, which is of great significance to the processing of OBN data; a completely data-driven method is used, and only the original seismic data and the expected wavelet need to be input to complete the directional elimination process of the far-field wavelet. No known prior information and human factors are required, and the calculation accuracy is high and easy to implement; in three dimensions The azimuth and exit angle information obtained in the domain avoids the problem that the low-frequency signal of seismic data does not converge with the increase of offset distance in the time and space domain. The domain can highlight low-frequency information more, easily identify the propagation period of low-frequency bubbles and ghost reflections at the shot point end, suppress the two, and thus improve the signal-to-noise ratio of the data; the "first arrival correction" + "small facet grid" method is adopted, among which the first arrival correction achieves the purpose of effective signal in-phase enhancement, and the small facet grid can more accurately calculate the azimuth and exit angle information, thus providing high-precision data guarantee for the subsequent synthesis of directional far-field wavelets; for pre-stack gather processing, multi-core parallel computing is realized, and the computing efficiency is fast; at the same time, taking advantage of the fact that pre-stack gathers are not very sensitive to underground structural changes, the matching operator calculated from one gather can be applied to several adjacent gathers, greatly reducing memory occupancy and computing cost. This technology is suitable for processing large amounts of seismic data.

[0129] like Figure 14 As shown, an embodiment of the present invention further provides a data-driven direction signal deconvolution device, the device comprising:

[0130] The data acquisition module 10 is used to acquire pre-stack seismic gather data and preset expected wavelets during seismic data acquisition;

[0131] The data transformation module 20 is used to sequentially perform Fourier forward transformation, three-dimensional transformation and transform and inverse Fourier transform to obtain first seismic data;

[0132] A time difference correction module 30 is used to perform time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data;

[0133] a first determining module 40 for projecting the azimuth of each seismic trace in the second seismic data onto a preset bin grid, determining a seismic trace in each bin, and forming first directional seismic data based on the seismic traces of all bins;

[0134] A second determining module 50 is configured to project the azimuth of each seismic trace in the first seismic data onto a preset bin grid and determine a seismic trace in each bin, and form second directional seismic data based on the seismic traces of all bins;

[0135] An operator determination module 60 is configured to obtain a direction matching operator based on the first directional seismic data and the preset expected wavelet;

[0136] The data output module 70 is used to modify the second directional seismic data using the direction matching operator and perform three-dimensional transformation on the modified data. Perform inverse transformation to obtain the final seismic gather data.

[0137] An embodiment of the present invention further provides a readable storage medium having instructions stored thereon, wherein the instructions are used to enable a machine to execute the above-mentioned data-driven directional signal deconvolution method.

[0138] Those skilled in the art will appreciate that all or part of the steps in the methods described in the aforementioned embodiments can be performed by instructing the relevant hardware through a program. The program, stored in a storage medium, includes instructions for causing a microcontroller, chip, or processor to execute all or part of the steps in the methods described in the various embodiments of the present invention. The aforementioned storage medium includes various media capable of storing program code, such as a USB flash drive, a mobile hard drive, a read-only memory (ROM), a random access memory (RAM), a magnetic disk, or an optical disk.

[0139] Those skilled in the art can clearly understand that, for the convenience and simplicity of description, only the division of the above-mentioned functional units and modules is used as an example for illustration. In actual applications, the above-mentioned functions can be distributed and completed by different functional units and modules as needed, that is, the internal structure of the device can be divided into different functional units or modules to complete all or part of the functions described above. The functional units and modules in the embodiment can be integrated into one processing unit, or each unit can exist physically alone, or two or more units can be integrated into one unit. The above-mentioned integrated unit can be implemented in the form of hardware or in the form of a software functional unit. In addition, the specific names of the functional units and modules are only for the convenience of distinguishing each other and are not used to limit the scope of protection of this application.

[0140] The above describes in detail the optional embodiments of the present invention in conjunction with the accompanying drawings. However, the embodiments of the present invention are not limited to the specific details in the above embodiments. Within the technical concept of the embodiments of the present invention, a variety of simple modifications can be made to the technical solutions of the embodiments of the present invention, and these simple modifications all fall within the scope of protection of the embodiments of the present invention. It should also be noted that the various specific technical features described in the above specific embodiments can be combined in any suitable manner unless there is any contradiction. In order to avoid unnecessary repetition, the embodiments of the present invention will no longer describe the various possible combinations separately.

[0141] In addition, the various embodiments of the present invention may be arbitrarily combined, and as long as they do not violate the concept of the embodiments of the present invention, they should also be regarded as the contents disclosed in the embodiments of the present invention.

Claims

1. A data-driven directional signal deconvolution method, characterized in that: The method comprises: Obtain pre-stack seismic gather data and preset expected wavelets during seismic data acquisition; The pre-stack seismic gather data are sequentially subjected to Fourier forward transform, three-dimensional transform and inverse Fourier transform to obtain first seismic data; Performing time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data; The azimuth of each seismic trace in the second seismic data is projected onto a preset bin grid, and a seismic trace is determined in each bin. The first directional seismic data is formed based on the seismic traces of all bins, wherein the ray parameters of each seismic trace in the second seismic data are used to correct the time difference of the second seismic data. and Calculating the horizontal azimuth angle and the vertical emission angle, and dividing the horizontal azimuth angle and the vertical emission angle into a preset bin grid according to a preset angle interval; Projecting the azimuth of each seismic trace in the first seismic data onto a preset bin grid, determining a seismic trace in each bin, and forming second directional seismic data based on the seismic traces of all bins; Obtaining a direction matching operator based on the first directional seismic data and the preset expected wavelet includes: Performing wavelet matching on the first directional seismic data and the preset expected wavelet to obtain a matching operator; Based on the matching operator, a direction matching operator is obtained using a least squares criterion; Specifically, the direction matching operator is obtained using the following formula: ； ； in, is the direction matching operator; is the wavelet of the first directional seismic data; is the preset expected wavelet; The second directional seismic data is corrected by using the direction matching operator, and the corrected data is subjected to three-dimensional Inverse transformation is performed to obtain the final seismic gather data, including: The final seismic gather data is obtained using the following formula: ； in, is the final seismic gather data; is the horizontal operator; is the second directional seismic data; is the direction matching operator; is the vertical operator.

2. The data-driven directional signal deconvolution method according to claim 1, characterized in that: The pre-stack seismic gather data are sequentially subjected to Fourier forward transform, three-dimensional Transformation and inverse Fourier transformation are performed to obtain the first seismic data, including: Based on the shot point coordinates and receiver point coordinates of pre-stack seismic gather data, the offset of each seismic trace is calculated; Performing a Fourier forward transform on the pre-stack seismic gather data along a time direction to obtain first seismic sub-data; Based on the offset of each seismic trace, the conjugate operator of the horizontal transformation operator and the vertical transformation operator is obtained; The seismic sub-data are subjected to three-dimensional conjugation based on the conjugate operator. Forward transformation to obtain the second seismic sub-data; Perform an inverse Fourier transform on the second seismic sub-data along the time direction to obtain the first seismic data.

3. The data-driven directional signal deconvolution method according to claim 2, characterized in that: The expression of the conjugate operator of the transverse transformation operator is: ； in, is the conjugate operator of the transverse transformation operator; is the circular frequency of the seismic data; for x Offset in direction; m is the number of horizontal seismic traces; is the transverse ray parameter; k for The number of channels in the horizontal direction of the domain; The expression of the conjugate operator of the longitudinal transformation operator is: ； in, is the conjugate operator of the longitudinal transformation operator; is the circular frequency of the seismic data; for y Offset in direction; n is the number of longitudinal seismic traces; is the longitudinal ray parameter; j for The number of lanes in the vertical direction of the domain.

4. The data-driven directional signal deconvolution method according to claim 1, wherein: Performing time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data includes: The following formula is used for time difference correction: ； in, is the second earthquake data; is the first earthquake data; is the intercept time at zero offset, is the layer velocity of the first layer of medium; and is the ray parameter of each seismic trace in the first seismic data; The distance from the calibration plane to the water surface.

5. The data-driven directional signal deconvolution method according to claim 1, wherein: The azimuth angle includes a horizontal azimuth angle and a vertical emission angle, and the method further includes: The horizontal azimuth angle and vertical emission angle are calculated using the following formula: ； ； in, is the horizontal azimuth; is the vertical exit angle; and is the ray parameter of each seismic trace; is the layer velocity of the first layer of medium.

6. A data-driven directional signal deconvolution device, characterized in that: The device comprises: A data acquisition module, used to obtain pre-stack seismic gather data and preset expected wavelets during seismic data acquisition; The data transformation module is used to sequentially perform Fourier forward transformation, three-dimensional transform and inverse Fourier transform to obtain first seismic data; a time difference correction module, configured to perform time difference correction on each seismic trace in the first seismic data in the same plane to obtain second seismic data; The first determination module is used to project the azimuth of each seismic trace in the second seismic data onto a preset bin grid, and determine a seismic trace in each bin, and form first directional seismic data based on the seismic traces of all bins, wherein the ray parameters of each seismic trace in the second seismic data are used to correct the time difference of the second seismic data. and Calculating the horizontal azimuth angle and the vertical emission angle, and dividing the horizontal azimuth angle and the vertical emission angle into a preset bin grid according to a preset angle interval; A second determining module is configured to project the azimuth of each seismic trace in the first seismic data onto a preset bin grid and determine a seismic trace in each bin, and form second directional seismic data based on the seismic traces of all bins; An operator determination module, configured to obtain a direction matching operator based on the first directional seismic data and the preset expected wavelet, comprising: Performing wavelet matching on the first directional seismic data and the preset expected wavelet to obtain a matching operator; Based on the matching operator, a direction matching operator is obtained using a least squares criterion; Specifically, the direction matching operator is obtained using the following formula: ； ； in, is the direction matching operator; is the wavelet of the first directional seismic data; is the preset expected wavelet; A data output module is used to modify the second directional seismic data using the direction matching operator and perform three-dimensional transformation on the modified data. Inverse transformation is performed to obtain the final seismic gather data, including: The final seismic gather data is obtained using the following formula: ； in, is the final seismic gather data; is the horizontal operator; is the second directional seismic data; is the direction matching operator; is the vertical operator.

7. A readable storage medium having instructions stored thereon, the instructions being used to enable a machine to execute the data-driven directional signal deconvolution method according to any one of claims 1 to 5.

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