Seismic data dynamic correction method, device and electronic equipment

Abstract

The present invention provides a method, device and electronic equipment for dynamic correction of seismic data, relating to the technical field of seismic data, including: acquiring zero-offset seismic reflection wave data, first and second seismic reflection wave data sets in a target work area; constructing a virtual reflection trace gather of a reference seismic trace based on the first seismic reflection wave data of the reference seismic trace and a specified seismic trace; determining an extrapolated super-virtual reflection trace gather of a second shot point based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection trace gather, and then constructing a non-zero-offset seismic reflection wave data set corresponding to the second shot point in combination with the second seismic reflection wave data set; performing dynamic correction processing on the non-zero-offset seismic reflection wave data set based on the zero-offset seismic reflection wave data to obtain a dynamically corrected seismic reflection wave data set. This method can increase the number of effective detection points and reflection points at large offsets, flatten the reflection wave isochrones, and improve the signal-to-noise ratio and resolution of seismic reflection wave data.

Description

Technical Field

[0001] The present invention relates to the technical field of seismic data processing, and in particular, to a method, apparatus, and electronic device for dynamic correction of seismic data. Background Art

[0002] Dynamic correction is a basic link in seismic data processing, and its function is to eliminate the influence of shot-receiver offset on the propagation time of reflected waves. The traditional dynamic correction method is the method of "moving point by point and interpolating in the middle", which is one of the main reasons for the stretching and distortion of wavelets, resulting in a decrease in the wavelet frequency and an increase in the waveform at shallow layers and large offset distances, which has an adverse impact on subsequent processing processes such as horizontal stacking, AVO analysis, wave impedance recovery, and inversion. However, for severely distorted parts, the excision method is usually adopted, which will lead to a shorter effective extended length of seismic exploration and a lower effective stacking times of underground reflection points, thereby reducing the resolution of the stacked section and having an adverse impact on finding fine traps. Summary of the Invention

[0003] The purpose of the present invention is to provide a method, apparatus, and electronic device for dynamic correction of seismic data to alleviate the technical problem of reduced resolution of seismic reflection wave data existing in the existing dynamic correction method of seismic data.

[0004] In a first aspect, the present invention provides a method for dynamic correction of seismic data, including: obtaining zero-offset seismic reflection wave data, a first set of seismic reflection wave data, and a second set of seismic reflection wave data in a target work area; wherein, the first set of seismic reflection wave data is a set of first seismic reflection wave data excited by a first shot point and received by all seismic channels; the second set of seismic reflection wave data is a set of second seismic reflection wave data excited by a second shot point and received by all seismic channels; the first shot point and the second shot point are shot points on the same survey line; constructing a virtual reflection trace gather of a reference trace based on the first seismic reflection wave data of the reference trace and the first seismic reflection wave data of a specified trace; wherein, the reference trace represents the seismic trace where the common geophone point farthest from the second shot point among all common geophone points of the first shot point and the second shot point is located; the specified trace represents a seismic trace whose distance from the first shot point is greater than the distance between the reference trace and the first shot point; determining an extrapolated super-virtual reflection trace gather of the second shot point based on the second seismic reflection wave data of the reference trace and the virtual reflection trace gather, so as to construct a non-zero-offset seismic reflection wave data set corresponding to the second shot point based on the extrapolated super-virtual reflection trace gather and the second set of seismic reflection wave data; performing dynamic correction processing on the non-zero-offset seismic reflection wave data set based on the zero-offset seismic reflection wave data to obtain a dynamically corrected seismic reflection wave data set.

[0005] In an alternative embodiment, a virtual reflection gather of a reference seismic trace is constructed based on first seismic reflection wave data of the reference seismic trace and first seismic reflection wave data of a specified seismic trace, including: calculating a third-order cumulant of the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of a target seismic trace to obtain target virtual reflection data; wherein the target seismic trace represents any one of the specified seismic traces; the target virtual reflection data represents virtual reflection data propagated between the reference seismic trace and the target seismic trace when the reference seismic trace is used as a virtual shot point; constructing a virtual reflection gather of the reference seismic trace based on a set of virtual reflection data propagated between the reference seismic trace and the specified seismic trace.

[0006] In an alternative embodiment, an extrapolated super-virtual reflection gather of a second shot point is determined based on second seismic reflection wave data of the reference seismic trace and the virtual reflection gather, including: performing a convolution calculation on the second seismic reflection wave data of the reference seismic trace and the target virtual reflection data to obtain a target convolution result; performing an integration process on the target convolution result on a closed surface formed by geophone points corresponding to the reference seismic trace to obtain a target integration result; determining target extrapolated super-virtual reflection data based on the target integration result; wherein the target extrapolated super-virtual reflection data represents seismic reflection wave data received by the target seismic trace excited by the second shot point; determining an extrapolated super-virtual reflection gather of the second shot point based on a set of seismic reflection wave data received by the specified seismic trace excited by the second shot point.

[0007] In an alternative embodiment, a set of moveout-corrected seismic reflection wave data is obtained by performing moveout correction on a set of non-zero-offset seismic reflection wave data based on zero-offset seismic reflection wave data, including: calculating a third-order cumulant of the zero-offset seismic reflection wave data and target non-zero-offset seismic reflection wave data to obtain a target travel time difference; wherein the target non-zero-offset seismic reflection wave data represents any one of the non-zero-offset seismic reflection wave data in the set of non-zero-offset seismic reflection wave data; the target travel time difference represents the travel time difference due to the offset between the target non-zero-offset seismic trace and the zero-offset seismic trace; calculating a third-order cumulant of the target travel time difference and the target non-zero-offset seismic reflection wave data to obtain moveout-corrected target non-zero-offset seismic reflection wave data; determining a set of moveout-corrected seismic reflection wave data based on all moveout-corrected non-zero-offset seismic reflection wave data.

[0008] In an alternative embodiment, the target virtual reflection data is determined by the following formula: where Im represents taking the imaginary part, G v (R i+n |R i ) represents when the reference seismic trace R i is used as a virtual shot point, the reference seismic trace R i and the target seismic trace R i+nThe ghost reflection data propagated between the target seismic trace R i+n With reference seismic trace R i The number of detection points between is n-1, cum represents the high-order cumulative calculation, G(R i+n |S i ) represents the target seismic trace R i+n The first seismic reflection wave data, S i Indicates the first shot point, G(R i |S i ) represents the reference seismic trace R i The first seismic reflection wave data, E represents the mathematical expectation, and the real part of the target virtual reflection data is 0.

[0009] In an optional embodiment, the target extrapolated super ghost reflection data is determined by the following formula: esv (R i+n |S j )=2ik∫G v (R i+n |R i )*G(R i |S j )d 2 R i ; where i represents the imaginary part, k = w / v, k represents the average wave number, w represents the frequency of the seismic wave, v represents the wave velocity, G v (R i+n |R i ) represents the reference seismic trace R i When it is a virtual shot point, refer to the seismic trace R i With the target seismic trace R i+n The ghost reflection data propagated between G(R i |Sj) represents the reference seismic trace R i The second seismic reflection wave data, S j Indicates the second shot point, G esv (R i+n |S j ) represents the target extrapolated super ghost reflection data.

[0010] In an optional embodiment, the target travel time difference is determined by the following formula: V(j; t j -t0)=cum{G esv (R j |S j ),G(R0|S0),G(R0|S0)}; where V(j; t j -t0) represents the target travel time difference, j represents the number of the seismic channel, t j Indicates the second shot point S j After excitation, the target non-zero offset seismic trace R jThe propagation time of the received target non-zero offset seismic reflection wave data, t0 represents the propagation time of the zero-offset seismic reflection wave data, cum represents the high-order cumulant calculation, G esv (R j |S j ) represents the seismic reflection wave data received by the target non-zero offset seismic trace R excited by the second shot point S j . The seismic reflection wave data received by the target non-zero offset seismic trace R j . G(R0|S0) represents the zero-offset seismic reflection wave data, and the zero-offset seismic reflection wave data represents the seismic reflection wave data excited by the shot point S0 and received by the seismic trace R0 corresponding to the geophone set at the shot point S0; the target non-zero offset seismic reflection wave data after NMO correction is determined by the following formula: G enmo (j, t0) = cum{V(j;t j -t0), G esv (R j |S j ), G esv (R j |S j )}; where G enmo (j, t0) represents the target non-zero offset seismic reflection wave data after NMO correction.

[0011] In a second aspect, the present invention provides a seismic data NMO correction device, including: an acquisition module, configured to acquire zero-offset seismic reflection wave data, a first set of seismic reflection wave data, and a second set of seismic reflection wave data in a target work area; wherein, the first set of seismic reflection wave data is a set of first seismic reflection wave data excited by a first shot point and received by all seismic traces; the second set of seismic reflection wave data is a set of second seismic reflection wave data excited by a second shot point and received by all seismic traces; the first shot point and the second shot point are shot points on the same survey line; a construction module, configured to construct a virtual reflection trace set of a reference seismic trace based on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of a specified seismic trace; wherein, the reference seismic trace represents the seismic trace where the common geophone farthest from the second shot point among all common geophones of the first shot point and the second shot point is located; the specified seismic trace represents a seismic trace whose distance from the first shot point is greater than the distance between the reference seismic trace and the first shot point; a determination module, configured to determine an extrapolated super-virtual reflection trace set of the second shot point based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection trace set, so as to construct a set of non-zero offset seismic reflection wave data corresponding to the second shot point based on the extrapolated super-virtual reflection trace set and the second set of seismic reflection wave data; an NMO correction module, configured to perform NMO correction processing on the set of non-zero offset seismic reflection wave data based on the zero-offset seismic reflection wave data to obtain a set of seismic reflection wave data after NMO correction.

[0012] In a third aspect, the present invention provides an electronic device, including a memory and a processor. A computer program that can run on the processor is stored on the memory. When the processor executes the computer program, the steps of the seismic data normal moveout method in any one of the foregoing embodiments are implemented.

[0013] In a fourth aspect, the present invention provides a computer-readable storage medium. The computer-readable storage medium stores computer instructions. When the computer instructions are executed by a processor, the seismic data normal moveout method in any one of the foregoing embodiments is implemented.

[0014] The present invention provides a seismic data normal moveout method. This method can construct an extrapolated virtual reflection trace gather of a second shot point when the number of shot-receiver pairs is limited. That is, it realizes the extrapolation of the reflected wave field of the second shot point to obtain the effective reflected wave signal beyond the maximum offset of the second shot point, thereby increasing the number of effective geophone points and reflection points at large offsets, enlarging the exploration aperture, and further increasing the effective stacking times of underground reflection points. Then, by using the zero-offset seismic reflection wave data to perform normal moveout processing on the non-zero-offset seismic reflection wave data set corresponding to the second shot point constructed from the extrapolated virtual reflection trace gather and the second seismic reflection wave data set, the reflection wave event can be flattened. Therefore, the method of the present invention can effectively improve the signal-to-noise ratio and resolution of seismic reflection wave data and restore the true shape of the formation interface. BRIEF DESCRIPTION OF THE DRAWINGS

[0015] In order to more clearly illustrate the specific embodiments of the present invention or the technical solutions in the prior art, the following will briefly introduce the drawings required for use in the description of the specific embodiments or the prior art. Obviously, the drawings in the following description are some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can be obtained based on these drawings.

[0016] Figure 1 It is a flowchart of a seismic data normal moveout method provided by an embodiment of the present invention;

[0017] Figure 2 It is a schematic diagram of the principle for constructing a virtual reflection trace gather of a reference seismic trace provided by an embodiment of the present invention;

[0018] Figure 3 It is a schematic diagram of the principle for constructing an extrapolated virtual reflection trace gather of a second shot point provided by an embodiment of the present invention;

[0019] Figure 4 It is a schematic diagram of the principle for calculating the travel time difference based on the third-order cumulant provided by an embodiment of the present invention;

[0020] Figure 5It is a schematic diagram of the principle for eliminating the influence of offset and realizing NMO processing based on the calculation of third-order cumulants provided by an embodiment of the present invention;

[0021] Figure 6 It is a schematic diagram of the effect after NMO processing provided by an embodiment of the present invention;

[0022] Figure 7 It is a comparison chart of NMO results between the traditional NMO method and the method of the present invention;

[0023] Figure 8 It is the result of reconstructing far-offset reflection waves by different NMO methods for low signal-to-noise ratio data containing cross events;

[0024] Figure 9 It is for applying the method of the present invention to respectively Figure 8 The schematic diagram of the result after NMO processing of the seismic reflection wave data in view (a), view (d) and view (e) in;

[0025] Figure 10 It is a functional module diagram of a seismic data NMO device provided by an embodiment of the present invention;

[0026] Figure 11 It is a schematic diagram of an electronic device provided by an embodiment of the present invention. Detailed implementation manners

[0027] To make the objectives, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are some, but not all, of the embodiments of the present invention. Usually, the components of the embodiments of the present invention described and illustrated herein can be arranged and designed in various different configurations.

[0028] Therefore, the following detailed description of the embodiments of the present invention provided in the drawings is not intended to limit the scope of the claimed present invention, but merely represents selected embodiments of the present invention. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present invention without creative efforts shall fall within the protection scope of the present invention.

[0029] The following will describe in detail some embodiments of the present invention with reference to the accompanying drawings. Without conflict, the following embodiments and the features in the embodiments can be combined with each other.

[0030] Traditional dynamic correction methods can lead to the problem of wavelet stretching distortion after dynamic correction of seismic reflection wave data. For severely distorted parts, excision methods are usually adopted. To overcome the problem of missing far-offset data caused by stretching excision, an embodiment of the present invention proposes a dynamic correction method for seismic data. This method is a stretch-free dynamic correction method based on extrapolation interference. By performing extrapolation operations, the original maximum offset of the shot gather is expanded, and on this basis, dynamic correction processing is realized through high-order interference methods, avoiding the stretching problem of far offsets. Thereby improving the signal-to-noise ratio and resolution of seismic reflection wave data.

[0031] Embodiment 1

[0032] Figure 1 The flowchart of a dynamic correction method for seismic data provided by an embodiment of the present invention is as Figure 1 shown, and the method specifically includes the following steps:

[0033] Step S102, obtain zero-offset seismic reflection wave data, a first set of seismic reflection wave data, and a second set of seismic reflection wave data in the target work area.

[0034] The purpose of implementing the embodiment of the present invention is to perform stretch-free dynamic correction on the seismic reflection wave data generated by the excitation of the second shot point. To achieve the above purpose, it is not only necessary to obtain the first set of seismic reflection wave data and the second set of seismic reflection wave data, but also necessary to obtain zero-offset seismic reflection wave data. Among them, the first set of seismic reflection wave data is a set of first seismic reflection wave data received by all seismic channels excited by the first shot point; the second set of seismic reflection wave data is a set of second seismic reflection wave data received by all seismic channels excited by the second shot point; the first shot point and the second shot point are shot points on the same survey line. The zero-offset seismic reflection wave data represents the seismic reflection wave data received by the seismic channel corresponding to the geophone located at the shot point.

[0035] Specifically, the embodiment of the present invention first extrapolates the reflection wave field of the second shot point by using the first set of seismic reflection wave data and the second set of seismic reflection wave data, thereby increasing the number of effective geophones and reflection points at far offsets of the second shot point, expanding the exploration aperture, and then using the zero-offset seismic reflection wave data to perform dynamic correction on the extrapolated seismic reflection wave field (non-zero-offset seismic reflection wave field) of the second shot point, thereby realizing stretch-free dynamic correction.

[0036] It is known that during geological exploration, the relative positions between shot points and geophone points are fixed. That is to say, if the position of a shot point changes, all geophone points will also move accordingly. Therefore, although the number of seismic traces corresponding to the first shot point is the same as that corresponding to the second shot point, the positions where the seismic traces are located are different. In view of the fact that the embodiments of the present invention need to use the first seismic reflection wave data set to complete the expansion of the second seismic reflection wave data set, the number of common geophone points between the first shot point and the second shot point is greater than or equal to 1.

[0037] Step S104, based on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the specified seismic trace, construct a virtual reflection trace set of the reference seismic trace.

[0038] Among them, the reference seismic trace refers to the seismic trace where the common geophone point farthest from the second shot point is located among all the common geophone points of the first shot point and the second shot point; the specified seismic trace refers to the seismic trace whose distance from the first shot point is greater than the distance between the reference seismic trace and the first shot point. For the sake of easy understanding, the positions of the reference seismic trace and the specified seismic trace are illustrated by way of example below. Suppose the first shot point is S1, and the distances between all seismic traces and the first shot point are in ascending order: {R1, R2, R3, R4, R5}, and the second shot point is S2, and the distances between all seismic traces and the second shot point are in ascending order: {R1’, R2’, R3’, R4’, R5’}, and it is known that R4’ is in the same position as R1, and R5’ is in the same position as R2. Thus, it can be seen that the first shot point and the second shot point have 2 common geophone points, and R5’ is the seismic trace where the common geophone point farthest from the second shot point S2 is located. Therefore, the reference seismic trace is R5’(R2). And, in view of the fact that the distances between the seismic traces {R3, R4, R5} and the first shot point S1 are all greater than the distance between the reference seismic trace R5’(R2) and the first shot point S1, the specified seismic traces are {R3, R4, R5}.

[0039] Figure 2 It is a schematic diagram of the principle for constructing a virtual reflection trace set of a reference seismic trace provided by the embodiments of the present invention. Figure 2 In it, S i represents the first shot point, R i represents the reference seismic trace, R i+1 and R i+2 are both specified seismic traces, and R i 、R i+1 and R i+2 are all within the maximum offset range of the seismic data of the first shot point S i . From Figure 2 it can be seen that the reference seismic trace R iThe received first seismic reflection wave data (i.e., the primary reflection wave, hereinafter referred to as the "primary wave") and the specified seismic trace R i+2 There is a common path in the received first seismic reflection wave data (i.e., the multiple reflection wave, hereinafter referred to as the "multiple wave"). If the common paths included in the propagation of the multiple wave of each specified seismic trace and the primary wave of the reference seismic trace are cancelled respectively, the virtual reflection trace gather of the reference seismic trace can be generated. The virtual reflection trace gather of the reference seismic trace represents the set of virtual reflection data propagated between the virtual shot point and the geophone points corresponding to the specified seismic traces when the geophone point corresponding to the reference seismic trace R i is the virtual shot point.

[0040] Step S106: Based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection trace gather, determine the extrapolated super-virtual reflection trace gather of the second shot point, so as to construct the non-zero offset seismic reflection wave data set corresponding to the second shot point based on the extrapolated super-virtual reflection trace gather and the second seismic reflection wave data set.

[0041] Figure 3 This is a schematic diagram of the principle for constructing the extrapolated super-virtual reflection trace gather of the second shot point provided by the embodiment of the present invention. Figure 3 In it, S j represents the second shot point. According to the definitions of the reference seismic trace and the specified seismic trace, it can be known that the reference seismic trace R i is within the maximum offset range of the second shot point S j , while the specified seismic trace R i+n ( Figure 3 exemplarily R i+1 and R i+2 ) is outside the maximum offset range of the second shot point S j .

[0042] Therefore, after pre-acquiring the second seismic reflection wave data excited by the second shot point and received by the reference seismic trace and determining the virtual reflection trace gather of the reference seismic trace, by convolving the second seismic reflection wave data of the reference seismic trace and the virtual reflection data in the virtual reflection trace gather respectively, the seismic reflection wave data excited by the second shot point S j and received by the specified seismic trace R i+n can be obtained, that is, the extrapolated super-virtual reflection data. In view of the fact that the specified seismic trace R i+n is outside the maximum offset range of the second shot point S j , therefore, through the processing of the above steps, the purpose of increasing the maximum offset of the second shot point S j , increasing the number of far-offset geophone points and the number of effective reflection points can be achieved.

[0043] After determining the extrapolated surface-related multiple gather of the second shot point, an embodiment of the present invention uses the union of the extrapolated surface-related multiple gather and the second seismic reflection wave data set as the non-zero offset seismic reflection wave data set corresponding to the second shot point.

[0044] Step S108: Perform NMO processing on the non-zero offset seismic reflection wave data set based on the zero offset seismic reflection wave data to obtain the NMO-processed seismic reflection wave data set.

[0045] It is known that there is a travel time difference caused by the offset between the non-zero offset seismic trace and the zero offset seismic trace reflection wave data. Therefore, taking the zero offset seismic reflection wave data as a reference, eliminating the travel time difference between each non-zero offset seismic reflection wave data in the non-zero offset seismic reflection wave data set and it can achieve NMO, that is, eliminate the influence of the non-zero offset, and obtain the NMO-processed seismic reflection wave data set.

[0046] An embodiment of the present invention provides a method for NMO of seismic data. This method can construct the extrapolated surface-related multiple gather of the second shot point when the number of shot-receiver pairs is limited, that is, realize the extrapolation of the reflected wave field of the second shot point to obtain the effective reflected wave signal beyond the maximum offset of the second shot point, thereby increasing the number of effective detection points and reflection points at large offsets, increasing the exploration aperture, and then increasing the effective stacking times of underground reflection points. Then, use the zero offset seismic reflection wave data to perform NMO processing on the non-zero offset seismic reflection wave data set corresponding to the second shot point constructed by the extrapolated surface-related multiple gather and the second seismic reflection wave data set, and the reflected wave isochrone can be flattened. Therefore, the method of the present invention can effectively improve the signal-to-noise ratio and resolution of seismic reflection wave data and restore the true shape of the formation interface.

[0047] In an optional embodiment, step S104 above, constructing the surface-related multiple gather of the reference seismic trace based on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the specified seismic trace, specifically includes the following steps:

[0048] Step S1041: Calculate the third-order cumulant of the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the target seismic trace to obtain the target surface-related multiple data; where the target seismic trace represents any seismic trace in the specified seismic trace; the target surface-related multiple data represents the surface-related multiple data propagated between the reference seismic trace and the target seismic trace when the reference seismic trace is used as the virtual shot point.

[0049] Step S1042: Construct the surface-related multiple gather of the reference seismic trace based on the set of surface-related multiple data propagated between the reference seismic trace and the specified seismic trace.

[0050] In the embodiment of the present invention, the common path is canceled by calculating the third-order cumulants of the multiple wave and the primary wave to obtain the virtual reflection gather. Specifically, the target virtual reflection data is determined by the following formula: where Im represents taking the imaginary part, and G v (R i+n |R i ) represents the virtual reflection data propagated between the reference seismic trace R i when it is used as the virtual shot point, between the reference seismic trace R i and the target seismic trace R i+n . The number of geophone points between the target seismic trace R i+n and the reference seismic trace R i is n - 1, cum represents the high-order cumulant calculation, and G(R i+n |S i ) represents the first seismic reflection wave data of the target seismic trace R i+n , S i represents the first shot point, and G(R i |S i ) represents the first seismic reflection wave data of the reference seismic trace R i . E represents the mathematical expectation, and the real part of the target virtual reflection data is 0. Based on the above formula, the virtual reflection data propagated between the reference seismic trace and each specified seismic trace can be calculated, and the set of all virtual reflection data is the virtual reflection gather of the reference seismic trace.

[0051] In an alternative embodiment, in the above step S106, based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection gather, the extrapolated super-virtual reflection gather of the second shot point is determined, which specifically includes the following steps:

[0052] Step S1061: Perform convolution calculation on the second seismic reflection wave data of the reference seismic trace and the target virtual reflection data to obtain the target convolution result.

[0053] Step S1062: Perform integral processing on the target convolution result on the closed surface formed by the geophone points corresponding to the reference seismic trace to obtain the target integral result.

[0054] Step S1063: Determine the target extrapolated super-virtual reflection data based on the target integral result; where the target extrapolated super-virtual reflection data represents the seismic reflection wave data received by the target seismic trace excited by the second shot point.

[0055] Step S1064: Determine the extrapolated super-virtual reflection gather of the second shot point based on the set of seismic reflection wave data received by the specified seismic trace excited by the second shot point.

[0056] In the embodiment of the present invention, the target extrapolated super-virtual reflection data is determined by the following formula: G esv (Ri+n |S j ) = 2ik∫G v (R i+n |R i ) * G(R i |S j )d 2 R i ; where i represents the imaginary part, k = w / v, k represents the average wave number, w represents the seismic wave frequency, v represents the wave velocity, G v (R i+n |R i ) represents the virtual reflection data propagated between the reference seismic trace R i as the virtual shot point, the reference seismic trace R i and the target seismic trace R i+n ; G(R i |S j ) represents the second seismic reflection wave data of the reference seismic trace R i , S j represents the second shot point, G esv (R i+n |S j ) represents the target extrapolated super-virtual reflection data.

[0057] Referring to the above formula, the seismic reflection wave data received by each specified seismic trace excited by the second shot point can be calculated respectively, that is, the extrapolated super-virtual reflection data. The set of all extrapolated super-virtual reflection data is the extrapolated super-virtual reflection trace gather of the second shot point. That is to say, through convolution calculation, the reflection wave data outside the original maximum offset of the second shot point can be reconstructed to generate the extrapolated super-virtual reflection trace gather.

[0058] Following the examples of the shot point and the seismic trace in the above text, the first shot point is S1, the corresponding seismic traces are {R1, R2, R3, R4, R5}, the second shot point is S2, the corresponding seismic traces are {R1’, R2’, R3’, R4’, R5’}, and the reference seismic trace is R5’(R2). Then, after extrapolating the reflection wave field of the second shot point, the non-zero offset seismic traces corresponding to the set of non-zero offset seismic reflection wave data are {R1’, R2’, R3’, R4’, R5’, R3, R4, R5}.

[0059] In an optional implementation manner, in the above step S108, performing dynamic correction processing on the set of non-zero offset seismic reflection wave data based on the zero offset seismic reflection wave data to obtain the set of dynamically corrected seismic reflection wave data specifically includes the following steps:

[0060] Step S1081: Calculate the third-order cumulant of the zero-offset seismic reflection wave data and the target non-zero-offset seismic reflection wave data to obtain the target travel time difference. Herein, the target non-zero-offset seismic reflection wave data represents any non-zero-offset seismic reflection wave data in the non-zero-offset seismic reflection wave data set; the target travel time difference represents the propagation travel time difference caused by the offset between the target non-zero-offset seismic trace and the zero-offset seismic trace.

[0061] Specifically, in the embodiment of the present invention, the third-order cumulant calculation is used to solve the travel time difference caused by the offset between the non-zero-offset seismic trace and the zero-offset seismic trace reflection wave data. Figure 4 FIG. is a schematic diagram of the principle for obtaining the travel time difference based on the third-order cumulant calculation provided by the embodiment of the present invention. Refer to Figure 4 , the propagation path of the zero-offset seismic trace reflection wave data is S0FR0, and the length is 2S0F. The propagation path of the non-zero-offset seismic trace reflection wave data is S j FR j , wherein, the length of the propagation path S j ′FR j ′ is also 2S0F. After the third-order cumulant calculation, the travel times of the reflection waves on the same propagation path length can cancel each other out, and the difference is the path length of S j S j ′+R j R j ′. The propagation travel time on this path is the travel time difference caused by the offset, that is, the required normal moveout.

[0062] In an optional embodiment, the target travel time difference is determined by the following formula: V(j;t j -t0)=cum{G esv (R j |S j ),G(R0|S0),G(R0|S0)}; wherein, V(j;t j -t0) represents the target travel time difference, that is, the normal moveout; j represents the seismic trace number, j takes values from 1 to J, and the value of J is the sum of the number of original seismic traces at the second shot point and the number of specified seismic traces, t j represents the propagation time of the target non-zero-offset seismic reflection wave data received by the target non-zero-offset seismic trace R j after the second shot point S j is excited, t0 represents the propagation time of the zero-offset seismic reflection wave data, that is, the self-excitation and self-reception time, cum represents the high-order cumulant calculation, and G esv (R j |S j ) represents the value obtained from the second shot point S jExcitation, target non-zero offset seismic trace R j Received seismic reflection wave data, G(R0|S0) represents zero-offset seismic reflection wave data, and the zero-offset seismic reflection wave data represents the seismic reflection wave data excited by the shot point S0 and received by the seismic trace R0 corresponding to the geophone set at the shot point S0.

[0063] Based on the formula of the target travel time difference, it can be known that when the selected data is the seismic reflection wave data of the same underground reflection point, by performing a third-order cumulant calculation on the zero-offset seismic reflection wave data and the non-zero offset seismic reflection wave data, after canceling out the propagation times required for the same-length wave propagation paths, the travel time difference caused by the offset, that is, the dynamic correction amount, is obtained.

[0064] Step S1082, perform a third-order cumulant calculation on the target travel time difference and the target non-zero offset seismic reflection wave data to obtain the dynamically corrected target non-zero offset seismic reflection wave data.

[0065] Specifically, after calculating the propagation travel time difference (that is, the target travel time difference) caused by the offset between the target non-zero offset seismic trace and the zero-offset seismic trace, the embodiment of the present invention then performs a third-order cumulant calculation to subtract the dynamic correction amount caused by the offset from the propagation travel time of the non-zero offset seismic trace reflection wave, realizing stretch-free dynamic correction.

[0066] Figure 5 This is a schematic diagram of the principle for eliminating the influence of the offset and realizing dynamic correction processing based on the third-order cumulant calculation provided by the embodiment of the present invention. As Figure 5 shown, the propagation path of the non-zero offset seismic trace reflection wave data is S j FR j , and the dynamic correction amount is the propagation travel time of the seismic reflection wave on the path of S j S j ′+R j R j ′. Through the calculation of the third-order cumulant, the propagation travel time difference caused by the offset can be canceled, and the remaining propagation path is S j ′FR j ′, and the path length is 2S0F. Therefore, the travel time difference is eliminated, the purpose of dynamic correction is achieved, and the influence of the offset is eliminated. Figure 6 This is a schematic diagram of the effect after dynamic correction provided by the embodiment of the present invention.

[0067] In an optional implementation manner, the dynamically corrected target non-zero offset seismic reflection wave data is determined by the following formula: G enmo (j,t0) = cum{V(j;t j -t0),G esv (Rj |S j ),G esv (R j |S j )}; where, G enmo (j, t0) represents the target non-zero offset seismic reflection wave data after NMO correction.

[0068] Step S1083, determine the set of seismic reflection wave data after NMO correction based on all the non-zero offset seismic reflection wave data after NMO correction.

[0069] After performing NMO correction on all the non-zero offset seismic reflection wave data in the non-zero offset seismic reflection wave data set according to the processing flow of the above steps S1081 to S1082, the set of seismic reflection wave data after NMO correction can be obtained.

[0070] To verify the effectiveness of the NMO correction method provided by the embodiments of the present invention and the traditional NMO correction method, the above two methods are respectively used to perform NMO correction on a set of seismic reflection wave data. It is known that the traditional correction method usually uses the method of "point-by-point moving". Whether it can flatten the event depends on whether the picked NMO correction velocity is correct. Figure 7 It is a comparison chart of the NMO correction results of the traditional NMO correction method and the method of the present invention. Figure 7 View (a) in it is the original seismic reflection wave data. Figure 7 View (b) in it is the NMO correction result of the traditional NMO correction method when the picked velocity is relatively large. Obviously, when the picked velocity is greater than the true velocity, the correction amount is too large, the event bends downward, and the NMO correction is excessive. Figure 7 View (c) in it is the NMO correction result of the traditional NMO correction method when the picked velocity is relatively small. When the picked velocity is relatively small, the correction amount is too small, the event bends upward, and the NMO correction is insufficient. From the above results, it can be determined that the traditional NMO correction method greatly depends on the correctness of the picked NMO correction velocity, and the accuracy of the picked NMO correction velocity determines the accuracy of the NMO correction result.

[0071] Figure 7 View (d) in it is the NMO correction result of the traditional NMO correction method when the picked velocity is accurate. Although the event of the reflection wave can be flattened at this time, however, the event is stretched in the shallow layer and at the far offset in the result of the traditional method, and the event becomes significantly thicker. This is another shortcoming of the traditional method.

[0072] Figure 7The (e) view in [description] is the result of NMO correction of the method of the present invention. The present invention calculates the travel time difference between non-zero offset seismic traces and zero offset seismic traces through third-order cumulants, and then cancels this travel time difference through another third-order cumulant calculation, eliminating the influence of offset, and does not require picking up the velocity. Therefore, the present invention can avoid relying on the correctness of NMO velocity picking. At the same time, the NMO correction result of the method of the present invention does not show obvious stretching problems at large offsets, overcoming the shortcoming of the traditional NMO method that the in-phase axis becomes thicker at large offsets.

[0073] To further verify the effectiveness of the method of the present invention, specifically, forward modeling is carried out using a three-layer horizontal layered medium, and strong noise is added at large offsets. Figure 8 It is the result of reconstructing the far-offset reflected wave by different NMO methods for low signal-to-noise ratio data with cross in-phase axes. Figure 8 The (a) view in [description] is a schematic diagram of seismic reflection wave data missing traces 51 - 80. Figure 8 The (b) view in [description] is a schematic diagram of complete seismic reflection wave data with noise. As can be seen from Figure 8 the (b) view, after adding strong noise, the reflected wave data at large offsets is basically masked, and it is difficult to extract effective information.

[0074] Figure 8 The (c) view to (e) view in [description] are respectively the far-offset original data, the far-offset data reconstructed by the traditional interference method and the method of the present invention. Obviously, both methods can effectively suppress noise and improve the signal-to-noise ratio of seismic reflection wave data. However, through comparison, it can be seen that the wavelet of the traditional interference method is severely deformed, especially at the intersection of the in-phase axes of the reflected waves, where artifacts and false in-phase axes are likely to occur. While the method of the present invention can suppress the deformation of the wavelet while effectively suppressing noise, and at the same time improve the signal-to-noise ratio and resolution of seismic data.

[0075] After noise suppression and reconstruction of far-offset reflected wave data, Figure 9 It is a schematic diagram of the result after applying the method of the present invention to perform NMO correction on the seismic reflection wave data in Figure 8 the (a) view, (d) view and (e) view in [description] respectively. Figure 9 The (a) view in [description] is a schematic diagram of the result after performing NMO correction on Figure 8 the (a) view in [description]. Figure 9 The (b) view in [description] is a schematic diagram of the result after performing NMO correction on Figure 8 the (d) view in [description]. Figure 9 The (c) view in [description] is a schematic diagram of the result after performing NMO correction on Figure 8 the (e) view in [description]. According to Figure 9It can be seen that, compared with a single reflection wave in-phase axis, artifacts will be generated after NMO correction of the cross-reflection wave data by the NMO correction method for interference. The cross in-phase axis is divided into four parts at the intersection point: before the intersection point of the first in-phase axis, after the intersection point of the first in-phase axis, before the intersection point of the second in-phase axis, and after the intersection point of the second in-phase axis. By calculating the correlation and higher-order cumulants of these four parts, the four pseudo in-phase axes shown in the figure can be obtained. By comprehensively comparing the results of the traditional interference method and the method of the present invention, it can be found that the pseudo in-phase axis in the result of the method of the present invention has the weakest energy, the smallest existence range, the highest signal-to-noise ratio of the effective signal, and the smallest sidelobe energy.

[0076] In summary, the NMO correction method for seismic data provided by the embodiments of the present invention is a stretch-free NMO correction method based on the high-order extrapolation interference method. Through the third-order cumulant and convolution operations between the multiple wave and the primary wave, the primary wave at a large offset is reconstructed, realizing the extrapolation of the reflection wave field under the condition of a limited number of shot-receiver pairs, constructing an effective reflection wave signal beyond the maximum offset, increasing the number of effective detection points and reflection points at a large offset, increasing the stacking times of underground reflection points, and increasing the exploration aperture. At the same time, through the calculation of the third-order cumulant, the additional propagation travel time caused by the offset influence between the non-zero offset seismic trace and the zero offset seismic trace is obtained and cancelled, avoiding the stretching problem of the in-phase axis of the reflection wave at a large offset, realizing stretch-free NMO correction, flattening the in-phase axis of the reflection wave, and thus restoring the true shape of the underground interface. Moreover, since the calculation of the third-order cumulant can better suppress the correlated noise and sidelobes in the seismic reflection wave, the distortion degree of the seismic sequence wavelet generated by the third-order cumulant is relatively low, which can effectively reduce the energy of the false in-phase axis, and thus effectively improve the signal-to-noise ratio and resolution of the seismic reflection wave data.

[0077] Embodiment 2

[0078] The embodiments of the present invention further provide a seismic data NMO correction device, which is mainly used to execute the seismic data NMO correction method provided in the above Embodiment 1. The following is a specific introduction to the seismic data NMO correction device provided by the embodiments of the present invention.

[0079] Figure 10 is a functional module diagram of a seismic data NMO correction device provided by an embodiment of the present invention. As Figure 10 shown, the device mainly includes: an acquisition module 10, a construction module 20, a determination module 30, and an NMO correction module 40, where:

[0080] An acquisition module 10 is configured to acquire zero-offset seismic reflection wave data, a first set of seismic reflection wave data, and a second set of seismic reflection wave data in a target work area; wherein, the first set of seismic reflection wave data is a set of first seismic reflection wave data received by all seismic channels excited by a first shot point; the second set of seismic reflection wave data is a set of second seismic reflection wave data received by all seismic channels excited by a second shot point; the first shot point and the second shot point are shot points on the same survey line.

[0081] A construction module 20 is configured to construct a virtual reflection trace gather of a reference seismic trace based on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of a specified seismic trace; wherein, the reference seismic trace represents the seismic trace where the common geophone point farthest from the second shot point among all common geophone points of the first shot point and the second shot point is located; the specified seismic trace represents a seismic trace whose distance from the first shot point is greater than the distance between the reference seismic trace and the first shot point.

[0082] A determination module 30 is configured to determine an extrapolated super-virtual reflection trace gather of the second shot point based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection trace gather, so as to construct a non-zero-offset seismic reflection wave data set corresponding to the second shot point based on the extrapolated super-virtual reflection trace gather and the second set of seismic reflection wave data.

[0083] A normal moveout module 40 is configured to perform normal moveout processing on the non-zero-offset seismic reflection wave data set based on the zero-offset seismic reflection wave data to obtain a normal moveout processed seismic reflection wave data set.

[0084] An embodiment of the present invention provides a seismic data normal moveout device, which can construct an extrapolated super-virtual reflection trace gather of the second shot point when the number of shot and receiver points is limited, that is, realize extrapolating the reflection wave field of the second shot point to obtain an effective reflection wave signal beyond the maximum offset of the second shot point, thereby increasing the number of effective geophone points and reflection points at large offsets, enlarging the exploration aperture, and further increasing the effective stacking times of underground reflection points. Then, by performing normal moveout processing on the non-zero-offset seismic reflection wave data set corresponding to the second shot point constructed from the extrapolated super-virtual reflection trace gather and the second set of seismic reflection wave data using the zero-offset seismic reflection wave data, the reflection wave isochrone can be flattened. Therefore, the device of the present invention can effectively improve the signal-to-noise ratio and resolution of seismic reflection wave data and restore the true shape of the formation interface.

[0085] Optionally, the construction module 20 is specifically configured to:

[0086] Perform third-order cumulant calculation on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the target seismic trace to obtain target virtual reflection data; wherein, the target seismic trace represents any seismic trace in the specified seismic traces; the target virtual reflection data represents the virtual reflection data propagated between the reference seismic trace and the target seismic trace when the reference seismic trace is used as the virtual shot point.

[0087] Based on the set of virtual reflection data propagated between the reference seismic trace and the specified seismic traces, construct the virtual reflection gather of the reference seismic trace.

[0088] Optionally, the determination module 30 is specifically configured to:

[0089] Perform convolution calculation on the second seismic reflection wave data of the reference seismic trace and the target virtual reflection data to obtain a target convolution result.

[0090] Perform integral processing on the target convolution result over the closed surface formed by the geophone points corresponding to the reference seismic trace to obtain a target integral result.

[0091] Determine the target extrapolated super-virtual reflection data based on the target integral result; wherein, the target extrapolated super-virtual reflection data represents the seismic reflection wave data received by the target seismic trace excited by the second shot point.

[0092] Based on the set of seismic reflection wave data received by the specified seismic traces excited by the second shot point, determine the extrapolated super-virtual reflection gather of the second shot point.

[0093] Optionally, the NMO correction module 40 is specifically configured to:

[0094] Perform third-order cumulant calculation on the zero-offset seismic reflection wave data and the target non-zero-offset seismic reflection wave data to obtain a target travel time difference; wherein, the target non-zero-offset seismic reflection wave data represents any non-zero-offset seismic reflection wave data in the set of non-zero-offset seismic reflection wave data; the target travel time difference represents the propagation travel time difference caused by the offset between the target non-zero-offset seismic trace and the zero-offset seismic trace.

[0095] Perform third-order cumulant calculation on the target travel time difference and the target non-zero-offset seismic reflection wave data to obtain the NMO-corrected target non-zero-offset seismic reflection wave data.

[0096] Determine the set of NMO-corrected seismic reflection wave data based on all the NMO-corrected non-zero-offset seismic reflection wave data.

[0097] Optionally, the target virtual reflection data is determined by the following formula: wherein, Im represents taking the imaginary part, G v (R i+n |R i ) represents using the reference seismic trace Ri When it is a virtual shot point, the reference seismic trace R i and the virtual reflection data propagated between the target seismic trace R i+n The number of geophones between the target seismic trace R i+n and the reference seismic trace R i is n - 1. cum represents the calculation of high - order cumulants. G(R i+n |S i ) represents the first seismic reflection wave data of the target seismic trace R i+n . S i represents the first shot point. G(R i |S i ) represents the first seismic reflection wave data of the reference seismic trace R i . E represents the mathematical expectation. The real part of the target virtual reflection data is 0.

[0098] Optionally, the target extrapolated super - virtual reflection data is determined by the following formula: G esv (R i+n |S j ) = 2ik∫G v (R i+n |R i ) * G(R i |S j )d 2 R i ; where i represents the imaginary part, k = w / v, k represents the average wave number, w represents the seismic wave frequency, v represents the wave speed, G v (R i+n |R i ) represents the virtual reflection data propagated between the reference seismic trace R i and the target seismic trace R i when the reference seismic trace R i+n is used as the virtual shot point. G(R i |S j ) represents the second seismic reflection wave data of the reference seismic trace R i . S j represents the second shot point. G esv (R i+n |S j ) represents the target extrapolated super - virtual reflection data.

[0099] Optionally, the target travel - time difference is determined by the following formula: V(j; t j - t0) = cum{G esv (R j |S j ), G(R0|S0), G(R0|S0)}; where V(j; t j - t0) represents the target travel - time difference, j represents the number of the seismic trace, tj Indicates the second shot point S j After excitation, the target non-zero offset seismic trace R j The propagation time of the received target non-zero offset seismic reflection wave data, t0 represents the propagation time of the zero offset seismic reflection wave data, cum represents the high-order cumulant calculation, G esv (R j |S j ) indicates that the target non-zero offset seismic trace R j is excited by the second shot point S j The received seismic reflection wave data, G(R0|S0) represents the zero offset seismic reflection wave data, and the zero offset seismic reflection wave data represents the seismic reflection wave data excited by the shot point S0 and received by the seismic trace R0 corresponding to the geophone set at the shot point S0.

[0100] The target non-zero offset seismic reflection wave data after NMO correction is determined by the following formula: G enmo (j,t0) = cum{V(j;t j -t0),G esv (R j |S j ),G esv (R j |S j )}; where G enmo (j,t0) represents the target non-zero offset seismic reflection wave data after NMO correction.

[0101] Embodiment III

[0102] Refer to Figure 11 , this embodiment of the present invention provides an electronic device, which includes: a processor 60, a memory 61, a bus 62, and a communication interface 63. The processor 60, the communication interface 63, and the memory 61 are connected through the bus 62; the processor 60 is configured to execute an executable module stored in the memory 61, such as a computer program.

[0103] Among them, the memory 61 may include a high-speed random access memory (RAM, Random Access Memory), and may also include a non-volatile memory (non-volatile memory), such as at least one disk memory. Through at least one communication interface 63 (which can be wired or wireless), a communication connection is established between this system network element and at least one other network element, and the Internet, wide area network, local area network, metropolitan area network, etc. can be used.

[0104] The bus 62 can be an ISA bus, a PCI bus, an EISA bus, etc. The bus can be divided into an address bus, a data bus, a control bus, etc. For the sake of convenience of representation,Figure 11 is represented by only one bidirectional arrow, but it does not mean that there is only one bus or one type of bus.

[0105] Among them, the memory 61 is used to store a program. After receiving an execution instruction, the processor 60 executes the program. The method executed by the device defined by the process disclosed in any embodiment of the foregoing embodiments of the present invention can be applied to the processor 60 or implemented by the processor 60.

[0106] The processor 60 may be an integrated circuit chip with signal processing capabilities. In the implementation process, each step of the above method can be completed by the integrated logic circuit in the hardware of the processor 60 or by the instructions in the form of software. The above-mentioned processor 60 may be a general-purpose processor, including a central processing unit (CPU for short), a network processor (NP for short), etc.; it may also be a digital signal processor (DSP for short), an application specific integrated circuit (ASIC for short), a field-programmable gate array (FPGA for short), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components. It can implement or execute the various methods, steps and logic block diagrams disclosed in the embodiments of the present invention. The general-purpose processor may be a microprocessor or the processor may also be any conventional processor, etc. The steps of the method disclosed in combination with the embodiments of the present invention can be directly embodied as being executed and completed by the hardware decoding processor, or executed and completed by the combination of the hardware and software modules in the decoding processor. The software module may be located in a mature storage medium in the art such as a random access memory, a flash memory, a read-only memory, a programmable read-only memory, or an electrically erasable programmable memory, a register, etc. This storage medium is located in the memory 61, and the processor 60 reads the information in the memory 61 and combines its hardware to complete the steps of the above method.

[0107] A computer program product of a seismic data dynamic correction method, device and electronic device provided by an embodiment of the present invention includes a computer-readable storage medium storing non-volatile program codes executable by a processor. The instructions included in the program codes can be used to execute the method described in the foregoing method embodiments. For specific implementation, reference can be made to the method embodiments and will not be elaborated here.

[0108] In addition, in each embodiment of the present invention, the functional units can be integrated in one processing unit, or each unit can exist physically alone, or two or more units can be integrated in one unit.

[0109] When the above-mentioned function is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a non-volatile computer-readable storage medium executable by a processor. Based on such an understanding, the technical solution of the present invention, in essence, or the part that contributes to the prior art, or a part of this technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device, etc.) to execute all or part of the steps of the methods described in various embodiments of the present invention. The aforementioned storage medium includes: various media such as USB flash drives, mobile hard disks, read-only memories (ROM, Read-Only Memory), random access memories (RAM, Random Access Memory), magnetic disks, or optical discs that can store program codes.

[0110] It should be noted that: similar reference numerals and letters represent similar items in the following drawings. Therefore, once an item is defined in one drawing, it does not need to be further defined and explained in subsequent drawings.

[0111] In the description of the present invention, it should be noted that the orientation or positional relationship indicated by the terms "center", "upper", "lower", "left", "right", "vertical", "horizontal", "inner", "outer", etc. is based on the orientation or positional relationship shown in the drawings, or the orientation or positional relationship in which the product of this invention is usually placed during use. It is only for the convenience of describing the present invention and simplifying the description, rather than indicating or implying that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and therefore should not be construed as a limitation to the present invention. In addition, the terms "first", "second", "third", etc. are only used for descriptive distinction and cannot be understood as indicating or implying relative importance.

[0112] In addition, terms such as "horizontal", "vertical", "hanging" do not mean that the components are required to be absolutely horizontal or hanging, but can be slightly inclined. For example, "horizontal" only means that its direction is more horizontal relative to "vertical", and does not mean that this structure must be completely horizontal, but can be slightly inclined.

[0113] In the description of the present invention, it should also be noted that unless otherwise clearly specified and limited, the terms "set", "install", "connect", "couple" should be understood in a broad sense. For example, it can be a fixed connection, a detachable connection, or an integral connection; it can be a mechanical connection or an electrical connection; it can be directly connected or indirectly connected through an intermediate medium, and it can be the communication inside two elements. For those of ordinary skill in the art, the specific meanings of the above terms in the present invention can be understood according to specific circumstances.

[0114] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit them; although the present invention has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that they can still modify the technical solutions described in the foregoing embodiments, or perform equivalent replacements on some or all of the technical features; and these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the various embodiments of the present invention.

Claims

1. A method for dynamic correction of seismic data, characterized in that: include: Acquire zero-offset seismic reflection wave data, a first seismic reflection wave data set, and a second seismic reflection wave data set in the target work area; wherein the first seismic reflection wave data set is a set of first seismic reflection wave data excited by a first shot point and received by all seismic channels; the second seismic reflection wave data set is a set of second seismic reflection wave data excited by a second shot point and received by all seismic channels; the first shot point and the second shot point are shot points on the same survey line; Based on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the designated seismic trace, a virtual reflection trace gather of the reference seismic trace is constructed; wherein the reference seismic trace represents the seismic trace where the common detection point farthest from the second shot point is located among all the common detection points of the first shot point and the second shot point; and the designated seismic trace represents the seismic trace whose distance from the first shot point is greater than the distance between the reference seismic trace and the first shot point; Determine an extrapolated super virtual reflection gather of the second shot point based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection gather, so as to construct a non-zero offset seismic reflection wave data set corresponding to the second shot point based on the extrapolated super virtual reflection gather and the second seismic reflection wave data set; Performing a dynamic correction process on the non-zero offset seismic reflection wave data set based on the zero offset seismic reflection wave data to obtain a seismic reflection wave data set after dynamic correction; Wherein, based on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the designated seismic trace, constructing the virtual reflection trace gather of the reference seismic trace comprises: Performing third-order cumulant calculation on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the target seismic trace to obtain target virtual reflection data; wherein the target seismic trace represents any seismic trace in the designated seismic trace; the target virtual reflection data represents the virtual reflection data propagated between the reference seismic trace and the target seismic trace when the reference seismic trace is used as a virtual shot point; Constructing a virtual reflection trace gather of the reference seismic trace based on a set of virtual reflection data propagated between the reference seismic trace and the designated seismic trace; The method of performing a dynamic correction process on the non-zero offset seismic reflection wave data set based on the zero offset seismic reflection wave data to obtain a seismic reflection wave data set after dynamic correction includes: Performing third-order cumulants calculation on the zero-offset seismic reflection wave data and the target non-zero-offset seismic reflection wave data to obtain a target travel time difference; wherein the target non-zero-offset seismic reflection wave data represents any non-zero-offset seismic reflection wave data in the non-zero-offset seismic reflection wave data set; the target travel time difference represents the propagation travel time difference between the target non-zero-offset seismic trace and the zero-offset seismic trace due to the offset; Performing third-order cumulants calculation on the target travel time difference and the target non-zero offset seismic reflection wave data to obtain the target non-zero offset seismic reflection wave data after dynamic correction; The normal move-corrected seismic reflection wave data set is determined based on all normal move-corrected non-zero offset seismic reflection wave data.

2. The seismic data dynamic correction method according to claim 1, characterized in that: Determining the extrapolated super-virtual reflection gather of the second shot point based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection gather comprises: Performing convolution calculation on the second seismic reflection wave data of the reference seismic trace and the target ghost reflection data to obtain a target convolution result; Integrating the target convolution result on a closed surface formed by detection points corresponding to the reference seismic trace to obtain a target integral result; Determine target extrapolated super-ghost reflection data based on the target integration result; wherein the target extrapolated super-ghost reflection data represents seismic reflection wave data received by the target seismic trace excited by the second shot point; Based on the set of seismic reflection wave data received by the designated seismic trace excited by the second shot point, an extrapolated super virtual reflection trace gather of the second shot point is determined.

3. The seismic data dynamic correction method according to claim 1, characterized in that: The target ghost reflection data is determined by the following formula: Among them, Im represents the imaginary part, G v (R i+n |R i ) represents the reference seismic trace R i When it is a virtual shot point, the reference seismic trace R i With the target seismic trace R i+n The ghost reflection data propagated between the target seismic trace R i+n With the reference seismic trace R i The number of detection points between is n-1, cum represents the high-order cumulative calculation, G(R i+n |S i ) represents the target seismic trace R i+n The first seismic reflection wave data, S i represents the first shot point, G(R i |S i ) represents the reference seismic trace R i The first seismic reflection wave data, E represents the mathematical expectation, and the real part of the target virtual reflection data is 0.

4. The seismic data dynamic correction method according to claim 2, characterized in that: The target extrapolated super ghost reflection data is determined by the following formula: esv (R i+n |S j )=2ik∫G v (R i+n |R i )*G(R i |S j )d 2 R i ; where i represents the imaginary part, k = w / v, k represents the average wave number, w represents the frequency of the seismic wave, v represents the wave velocity, G v (R i+n |R i ) represents the reference seismic trace R i When it is a virtual shot point, the reference seismic trace R i With the target seismic trace R i+n The ghost reflection data propagated between G(R i |S j ) represents the reference seismic trace R i The second seismic reflection wave data, S j represents the second shot point, G esv (R i+n |S j ) represents the target extrapolated super ghost reflection data.

5. The seismic data dynamic correction method according to claim 1, characterized in that: The target travel time difference is determined by the following formula: V(j; t j -t0)=cum{G esv (R j |S j ),G(R0|S0),G(R0|S0)}; Among them, V(j;t j -t0) represents the target travel time difference, j represents the number of the seismic channel, t j Indicates the second shot point S j After excitation, the target non-zero offset seismic trace R j The propagation time of the received target non-zero offset seismic reflection wave data, t0 represents the propagation time of the zero offset seismic reflection wave data, cum represents the high-order cumulant calculation, G esv (R j |S j ) represents the second shot point S j Excitation, target non-zero offset seismic trace R j The received seismic reflection wave data, G(R0|S0) represents the zero-offset seismic reflection wave data, and the zero-offset seismic reflection wave data represents the seismic reflection wave data excited by the shot point S0 and received by the seismic trace R0 corresponding to the detection point set at the shot point S0; The target non-zero offset seismic reflection wave data after the dynamic correction is determined by the following formula: enmo (j,t0)=cum{V(j;t j -t0),G esv (R j |S j ),G esv (R j |S j )}; where G enmo (j, t0) represents the target non-zero offset seismic reflection wave data after the dynamic correction.

6. A seismic data dynamic correction device, characterized in that: include: An acquisition module is used to acquire zero-offset seismic reflection wave data, a first seismic reflection wave data set, and a second seismic reflection wave data set in a target work area; wherein the first seismic reflection wave data set is a set of first seismic reflection wave data excited by a first shot point and received by all seismic channels; the second seismic reflection wave data set is a set of second seismic reflection wave data excited by a second shot point and received by all seismic channels; the first shot point and the second shot point are shot points on the same survey line; A construction module, for constructing a virtual reflection trace gather of a reference seismic trace based on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the designated seismic trace; wherein the reference seismic trace represents a seismic trace where a common detection point farthest from the second shot point is located among all common detection points of the first shot point and the second shot point; and the designated seismic trace represents a seismic trace whose distance from the first shot point is greater than the distance between the reference seismic trace and the first shot point; A determination module, configured to determine an extrapolated super virtual reflection gather of the second shot point based on the second seismic reflection wave data of the reference seismic trace and the virtual reflection gather, so as to construct a non-zero offset seismic reflection wave data set corresponding to the second shot point based on the extrapolated super virtual reflection gather and the second seismic reflection wave data set; A dynamic correction module, used for performing dynamic correction processing on the non-zero offset seismic reflection wave data set based on the zero offset seismic reflection wave data to obtain a seismic reflection wave data set after dynamic correction; The building blocks are specifically used for: Performing third-order cumulant calculation on the first seismic reflection wave data of the reference seismic trace and the first seismic reflection wave data of the target seismic trace to obtain target virtual reflection data; wherein the target seismic trace represents any seismic trace in the designated seismic trace; the target virtual reflection data represents the virtual reflection data propagated between the reference seismic trace and the target seismic trace when the reference seismic trace is used as a virtual shot point; Constructing a virtual reflection trace gather of the reference seismic trace based on a set of virtual reflection data propagated between the reference seismic trace and the designated seismic trace; The dynamic correction module is specifically used for: Performing third-order cumulants calculation on the zero-offset seismic reflection wave data and the target non-zero-offset seismic reflection wave data to obtain a target travel time difference; wherein the target non-zero-offset seismic reflection wave data represents any non-zero-offset seismic reflection wave data in the non-zero-offset seismic reflection wave data set; the target travel time difference represents the propagation travel time difference between the target non-zero-offset seismic trace and the zero-offset seismic trace due to the offset; Performing third-order cumulants calculation on the target travel time difference and the target non-zero offset seismic reflection wave data to obtain the target non-zero offset seismic reflection wave data after dynamic correction; The normal move-corrected seismic reflection wave data set is determined based on all normal move-corrected non-zero offset seismic reflection wave data.

7. An electronic device comprising a memory and a processor, wherein the memory stores a computer program that can be run on the processor, wherein: When the processor executes the computer program, the steps of the seismic data dynamic correction method described in any one of claims 1 to 5 are implemented.

8. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer instructions, and when the computer instructions are executed by a processor, the seismic data dynamic correction method according to any one of claims 1 to 5 is implemented.

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