A seismic data merging method

Abstract

This invention belongs to the field of seismic data processing technology for petroleum exploration. It discloses a method for processing contiguous seismic data. The method involves coherent enhancement and Fourier transform of seismic traces in seismic data A and B, obtaining the phase and amplitude spectral factors of each trace in the frequency domain. After smoothing, the values ​​are summed and averaged to obtain the phase and amplitude factors in the frequency domain. Then, an inverse Fourier transform is performed to convert the data to the time domain, yielding phase and amplitude shaping operators. These operators are then convolved and sequentially applied to seismic data A to achieve contiguous data shaping from seismic data A to seismic data B. This invention is used for contiguous processing of seismic data and has advantages such as good stability, high accuracy, and strong applicability.

Description

Technical Field

[0001] This invention belongs to the field of seismic data processing technology for petroleum exploration, and relates to a method for processing seismic data in contiguous patches. Background Technology

[0002] Because seismic data from different blocks vary in terms of excitation factors, reception conditions, and acquisition times, a series of consistency processing steps (such as static correction and amplitude processing) are required when processing contiguous seismic data. Even after resolving consistency issues, differences in time difference, amplitude, and phase still exist in the seismic data, preventing in-phase superposition of the contiguous data. Therefore, wavelet shaping processing is necessary for the contiguous seismic data from different blocks.

[0003] In recent years, with the development of marine processing technology, marine seismic exploration has become a major new business growth point in overseas markets, and the demand for contiguous processing of marine data has gradually become prominent. Marine data processing requires extremely high precision, with stringent requirements on everything from time difference to resolution. However, the precision of traditional onshore contiguous processing techniques falls far short of these requirements. Specifically, even after consistency processing, onshore seismic data may still exhibit an overall time difference of several milliseconds, differences in amplitude variation with frequency (i.e., bandwidth and the relative amplitude relationship between high and low frequency components), and differences in phase variation with frequency. All of these problems are difficult to solve simultaneously through wavelet shaping alone, because the actual output during wavelet shaping cannot perfectly match the expected output, especially when the difference is significant, resulting in unsatisfactory results. Therefore, it is necessary to research a method with good stability, high precision, and strong applicability to achieve contiguous matching of seismic data during marine seismic exploration. Summary of the Invention

[0004] The purpose of this invention is to provide a method for processing seismic data consolidation. By separately shaping the phase spectrum and amplitude spectrum of two seismic data sets to be consolidated, the method offers better operability and control in practical data applications, laying a solid foundation for improving the quality of consolidated data processing.

[0005] To achieve the above objectives, the technical solution adopted by this invention is as follows:

[0006] A method for processing seismic data in contiguous patches, characterized by comprising the following steps:

[0007] S1. Denote the two seismic data to be processed as seismic data A and seismic data B. Perform coherent enhancement on the seismic traces included in seismic data A and seismic data B to achieve signal enhancement processing.

[0008] S2. Perform Fourier transform on each seismic trace of the signal-enhanced seismic data A and seismic data B to transform the data to the frequency domain and separate the phase spectrum and amplitude spectrum in the frequency domain.

[0009] S3. In the frequency domain, subtract the phase spectrum of seismic data A from the phase spectrum of seismic data B corresponding to the seismic trace to obtain the phase spectrum factor of each seismic trace when shaping seismic data A into seismic data B; divide the amplitude spectrum of seismic data B corresponding to the seismic trace by the amplitude spectrum of seismic data A to obtain the amplitude spectrum factor of each seismic trace when shaping seismic data A into seismic data B.

[0010] S4. In the frequency domain, perform median filtering or mean filtering smoothing on the phase spectral factor and amplitude spectral factor of each seismic trace when shaping seismic data A to seismic data B. Then, sum and average the phase spectral factor and amplitude spectral factor of each seismic trace to obtain the frequency domain phase factor and frequency domain amplitude factor of seismic data A to seismic data B, and obtain the frequency domain phase operator and frequency domain amplitude operator of seismic data A to seismic data B.

[0011] S5. Perform inverse Fourier transform on the frequency domain phase operator and frequency domain amplitude operator for shaping seismic data A to seismic data B respectively to obtain the time domain phase shaping operator and amplitude shaping operator for shaping seismic data A to seismic data B as the frequency varies.

[0012] S6. The obtained phase shaping operator and amplitude shaping operator are convolved and applied sequentially to seismic data A to achieve continuous shaping processing from seismic data A to seismic data B.

[0013] As a limitation, the process of coherent enhancement of seismic data A and seismic data B in step S1 is as follows:

[0014] S11. Select several adjacent seismic traces from seismic data A and seismic data B for stacking, and use the i-th seismic trace on the stacked profile of seismic data A as the basis for stacking. The i-th seismic trace on the B-stack profile of seismic data Centered on the data, L seismic traces are taken on each side. The average value of 2L+1 seismic traces is taken as the model trace of that seismic trace in seismic data A and seismic data B. Where i = 1, 2, ..., n, n is the total number of seismic traces on the stacked profile; j = 1, 2, ..., l, l is the number of sampling points of the seismic trace.

[0015] S12. The model traces of seismic data A and seismic data B from step S11 are superimposed again at different dip angles within each time window. The dip angle with the strongest energy is then identified and used as the model trace for that seismic trace in the final seismic data A. And the model trace of that seismic trace in seismic data B

[0016] S13, transfer the seismic traces of seismic data A And its corresponding model Perform wave mixing and extract the seismic traces from seismic data B. And its corresponding model Perform mixing to obtain the mixing channels of seismic data A and seismic data B;

[0017]

[0018]

[0019] Where K is the percentage of mixing;

[0020] S14. Calculate the seismic data A model trace within a time window that slides along the seismic trace. Model trace of earthquake data B and corresponding mixing channel The cross-correlation function and autocorrelation function are used to obtain the weighting function for seismic data A and seismic data B;

[0021]

[0022]

[0023] Where Lc is half the length of the cross-correlation window; This indicates the mixing channel within the correlation window of seismic data A. The mixing channel within the B-correlation window of the seismic data. This represents the model trace within the correlation window of seismic data A. This represents the model trace within the correlation window of seismic data B;

[0024] Smoothing is applied to the weighted function of seismic data A and seismic data B:

[0025]

[0026]

[0027] Where Ls represents the smoothing radius, This represents the weighting function within the correlation window of seismic data A; This represents the weighting function within the correlation window of the seismic data B;

[0028] S15. Using the weighting function of the smoothed seismic data A and seismic data B as the weights of the corresponding model traces, apply the weights to the seismic traces to be processed. and Perform weighted summation to find the coherent strengthening path;

[0029]

[0030]

[0031] As a second limitation, in step S2, the formula for performing Fourier transform on each seismic trace of the signal-enhanced seismic data A and seismic data B is as follows:

[0032]

[0033]

[0034] in, Let A be the frequency domain of the i-th seismic trace in seismic data A, and the time domain... correspond, For the frequency domain and time domain of seismic data B, see the i-th seismic trace. Correspondingly; ω represents the angular frequency, ω = 2πf, where f is the frequency. It is the amplitude spectrum of the i-th seismic trace in seismic data A. It is the amplitude spectrum of the i-th seismic trace in seismic data B. It is the phase spectrum of the i-th seismic trace in seismic data A; It is the phase spectrum of the i-th seismic trace in seismic data B.

[0035] As a third limitation, in step S3, the formula for calculating the phase spectral factor of each seismic trace during the shaping of seismic data A into seismic data B is as follows:

[0036]

[0037] The formula for calculating the amplitude spectral factor of each seismic trace during seismic data A-to-seismic data B shaping is as follows:

[0038]

[0039] As a fourth constraint, the size of the filter template is E*E, where 5≤E≤31.

[0040] As a fifth limitation, in step S4, the phase spectral factor of each seismic trace during the shaping of seismic data A to seismic data B. And amplitude spectrum factor The formula for summing and averaging is:

[0041]

[0042]

[0043] Where T1(ω) is the final frequency domain amplitude factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B, and Φ1(ω) is the final frequency domain phase factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B.

[0044] The formulas for the frequency domain phase operator and the frequency domain amplitude operator are as follows:

[0045]

[0046]

[0047] Among them, X phase (ω) is the frequency-domain phase operator for shaping seismic data A into seismic data B, X amplitude (ω) is the frequency domain amplitude operator for shaping seismic data A into seismic data B.

[0048] As a sixth limitation, in step S5, the formulas for performing inverse Fourier transforms on the frequency domain phase operator and the frequency domain amplitude operator are as follows:

[0049]

[0050]

[0051] Where, x phase (t) is the time-domain phase shaping operator for shaping seismic data A to seismic data B, x amplitude (t) is the time-domain amplitude shaping operator for shaping seismic data A into seismic data B.

[0052] As a seventh limitation, in step S6, the formula for the convolution of the phase shaping operator and the amplitude shaping operator is:

[0053] x' A =x A (t)·x phasw (t)·x amplitude (t);

[0054] Where, x A (t) represents the seismic data A before contiguous shaping, x' A (t) represents the seismic data after the contiguous shaping of seismic data A into seismic data B.

[0055] The present invention, by adopting the above-described technical solution, achieves the following technical advancements compared to existing technologies:

[0056] (1) This invention separates the phase spectrum and amplitude spectrum in the frequency domain by Fourier transform, and then performs inverse Fourier transform on the phase factor and amplitude factor, which breaks through the limitations of traditional wavelet shaping technology and improves the accuracy and stability of data matching.

[0057] (2) After the seismic data of the present invention is matched in a continuous pattern, the results are closer to the target data in terms of phase and amplitude spectrum than those of conventional continuous pattern matching technology. This effectively solves the problem of severe amplitude spectrum jitter and instability after conventional continuous pattern matching, and the amplitude of different frequency bands is more consistent with the target data.

[0058] (3) By shaping the phase spectrum and amplitude spectrum of two seismic data to be processed separately, this invention has better operability and control in the application of actual data, laying a solid foundation for improving the quality of data processing.

[0059] (4) This method has the advantages of good stability, high accuracy and strong applicability. It has a wide range of applications and high value. It can effectively improve the imaging quality of seismic data, obtain processing results that can accurately reflect the underground geological conditions, provide a high-fidelity data basis for interpreting well locations, effectively improve the drilling success rate and reduce exploration risks.

[0060] This invention belongs to the field of petroleum exploration seismic data processing technology and is used to achieve contiguous processing of seismic data. Attached Figure Description

[0061] Figure 1 The diagram shown is a flowchart of a method according to an embodiment of the present invention;

[0062] Figure 2 The image shown is the imaging result of seismic data A in an embodiment of the present invention;

[0063] Figure 3 The image shown is the imaging result of seismic data B in an embodiment of the present invention;

[0064] Figure 4 The diagram shown is a flowchart of a conventional continuous matching technique.

[0065] Figure 5 The image shown is the imaging result after merging images using conventional merging matching technology;

[0066] Figure 6 The image shown is the imaging result after merging the images according to an embodiment of the present invention;

[0067] Figure 7 The figure shown is a comparison of the amplitude spectrum before and after the splicing matching of the embodiment of the present invention and the conventional splicing matching technology;

[0068] Figure 8The figure shown is a comparison of the correlation between the embodiment of the present invention, conventional contiguous matching technology, and seismic data A and seismic data B.

[0069] Figure 9 The figure shows the contiguous matching results of different expected outputs of the embodiments of the present invention in another application scenario;

[0070] Figure 10 The figure shown is a comparison of the amplitude spectra of seismic data before matching and the matching results with different expected outputs in another application scenario of the present invention. Detailed Implementation

[0071] To better explain and facilitate understanding of the present invention, the present invention will be described in detail below with reference to the accompanying drawings and specific embodiments.

[0072] Example: A method for processing seismic data in contiguous patches

[0073] Before performing seismic data consolidation processing in this embodiment, seismic data of the target area is first acquired, and the seismic data of the target area is subjected to pre-consolidation consistency processing. The processing of land seismic data involves consolidation static correction processing, consolidation surface consistency amplitude processing, and consolidation surface consistency deconvolution processing; the processing of marine seismic data involves consistency amplitude processing and consistency time difference correction.

[0074] like Figure 1 As shown, this embodiment includes the following steps:

[0075] S1. Denote the two seismic data sets to be processed as seismic data A and seismic data B. Perform coherent enhancement on the seismic traces included in seismic data A and seismic data B to improve the signal-to-noise ratio and achieve signal enhancement processing; for example... Figure 2 and Figure 3 The image shown is the imaging result of seismic data A and seismic data B in this step.

[0076] In this step, the process of coherently enhancing the seismic traces of seismic data A and seismic data B is as follows:

[0077] S11. Select several adjacent seismic traces from seismic data A and seismic data B for stacking, and use the i-th seismic trace on the stacked profile of seismic data A as the basis for stacking. The i-th seismic trace on the B-stack profile of seismic data Centered on the data, L seismic traces are taken on each side. The average value of 2L+1 seismic traces is taken as the model trace of that seismic trace in seismic data A and seismic data B. Where i = 1, 2, ..., n, n is the total number of seismic traces on the stacked profile; j = 1, 2, ..., l, l is the number of sampling points of the seismic trace.

[0078] S12. The model traces of seismic data A and seismic data B from step S11 are superimposed again at different dip angles within each time window. The dip angle with the strongest energy is then identified and used as the model trace for that seismic trace in the final seismic data A. And the model trace of that seismic trace in seismic data B

[0079] S13, transfer the seismic traces of seismic data A And its corresponding model Perform wave mixing and extract the seismic traces from seismic data B. And its corresponding model Perform mixing to obtain the mixing channels of seismic data A and seismic data B;

[0080]

[0081]

[0082] Where K is the percentage of mixing;

[0083] S14. Calculate the seismic data A model trace within a time window that slides along the seismic trace. Model trace of earthquake data B and corresponding mixing channel The cross-correlation function and autocorrelation function are used to obtain the weighting function for seismic data A and seismic data B;

[0084]

[0085]

[0086] Where Lc is half the length of the cross-correlation window; This indicates the mixing channel within the correlation window of seismic data A. The mixing channel within the B-correlation window of the seismic data. This represents the model trace within the correlation window of seismic data A. This represents the model trace within the correlation window of seismic data B;

[0087] Smoothing is applied to the weighted function of seismic data A and seismic data B:

[0088]

[0089]

[0090] Where Ls represents the smoothing radius, This represents the weighting function within the correlation window of seismic data A; This represents the weighting function within the correlation window of the seismic data B;

[0091] S15. Using the weighting function of the smoothed seismic data A and seismic data B as the weights of the corresponding model traces, apply the weights to the seismic traces to be processed. and Perform weighted summation to find the coherent strengthening path;

[0092]

[0093]

[0094] S2. Perform Fourier transform on each seismic trace of the signal-enhanced seismic data A and seismic data B to transform the data to the frequency domain and separate the phase spectrum and amplitude spectrum in the frequency domain.

[0095] In this step, the formula for performing Fourier transform on each seismic trace of the signal-enhanced seismic data A and seismic data B is as follows:

[0096]

[0097]

[0098] in, Let A be the frequency domain of the i-th seismic trace in seismic data A, and the time domain... correspond, For the frequency domain and time domain of seismic data B, see the i-th seismic trace. Correspondingly; ω represents the angular frequency, ω = 2πf, where f is the frequency. It is the amplitude spectrum of the i-th seismic trace in seismic data A. It is the amplitude spectrum of the i-th seismic trace in seismic data B. It is the phase spectrum of the i-th seismic trace in seismic data A; It is the phase spectrum of the i-th seismic trace in seismic data B;

[0099] S3. In the frequency domain, subtract the phase spectrum of seismic data A from the phase spectrum of seismic data B corresponding to the seismic trace to obtain the phase spectrum factor of each seismic trace when shaping seismic data A into seismic data B; divide the amplitude spectrum of seismic data B corresponding to the seismic trace by the amplitude spectrum of seismic data A to obtain the amplitude spectrum factor of each seismic trace when shaping seismic data A into seismic data B.

[0100] In this step, the formula for calculating the phase spectral factor of each seismic trace during the shaping of seismic data A into seismic data B is as follows:

[0101]

[0102] The formula for calculating the amplitude spectral factor of each seismic trace during seismic data A-to-seismic data B shaping is as follows:

[0103]

[0104] S4. In the frequency domain, perform median filtering or mean filtering smoothing on the phase spectral factor and amplitude spectral factor of each seismic trace when shaping seismic data A to seismic data B. Then, sum and average the phase spectral factor and amplitude spectral factor of each seismic trace to obtain the frequency domain phase factor and frequency domain amplitude factor of seismic data A to seismic data B, and obtain the frequency domain phase operator and frequency domain amplitude operator of seismic data A to seismic data B.

[0105] Wherein, the size of the filter template is E*E, 5≤E≤31, and the size of the filter template in this step is 5*5;

[0106] Phase spectral factor of each seismic trace during seismic data A to seismic data B shaping And amplitude spectrum factor The formula for summing and averaging is:

[0107]

[0108]

[0109] Where T1(ω) is the final frequency domain amplitude factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B, and Φ1(ω) is the final frequency domain phase factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B.

[0110] The formulas for the frequency domain phase operator and the frequency domain amplitude operator are as follows:

[0111]

[0112] X amplitude (ω)=T1(ω)e i·0

[0113] Among them, X phase (ω) is the frequency-domain phase operator for shaping seismic data A into seismic data B, X amplitude (ω) is the frequency domain amplitude operator for shaping seismic data A into seismic data B. As can be seen from the formula, the amplitude spectrum of the phase operator is one, indicating that it only changes the phase of different frequencies; while the phase of the amplitude operator is zero, indicating that it only processes the amplitude of different frequencies, that is, only the phase operator is applied and the amplitude operator is not applied.

[0114] S5. Perform inverse Fourier transform on the frequency domain phase operator and frequency domain amplitude operator for shaping seismic data A to seismic data B respectively to obtain the time domain phase shaping operator and amplitude shaping operator for shaping seismic data A to seismic data B as the frequency varies.

[0115] The formulas for performing inverse Fourier transforms on the frequency domain phase operator and the frequency domain amplitude operator are as follows:

[0116]

[0117]

[0118] Where, x phase (t) is the time-domain phase shaping operator for shaping seismic data A to seismic data B, x amplitude (t) is the time-domain amplitude shaping operator for shaping seismic data A into seismic data B;

[0119] S6. The obtained phase shaping operator and amplitude shaping operator are convolved and applied sequentially to seismic data A to achieve continuous shaping processing from seismic data A to seismic data B.

[0120] In this step, the formulas for the convolution of the phase shaping operator and the amplitude shaping operator are as follows:

[0121] x' A (t)=x A (t)·x phasw (t)·x amplitude (t);

[0122] Where, x A (t) represents the seismic data A before contiguous shaping, x' A (t) represents the seismic data after the contiguous shaping of seismic data A into seismic data B.

[0123] like Figure 4 The diagram shown is a flowchart of a conventional continuous matching technique. Figures 5-7 As shown, comparing the contiguous imaging result of seismic data A to seismic data B obtained by the present invention (only the phase operator is applied, not the amplitude operator, denoted as A2) with the contiguous imaging result of seismic data A to seismic data B obtained by conventional contiguous matching technology (denoted as A1), it can be seen that the contiguous imaging result A1 after using conventional contiguous matching technology obviously has a certain degree of high frequency loss, and the amplitude spectrum fluctuates violently and is unstable. Figure 5 and Figure 6 respectively with Figure 3A comparison of the imaging results from seismic data B shows that the contiguous imaging result A2 obtained by this invention, which combines seismic data A and seismic data B, has a better match with the imaging result of seismic data B. This demonstrates that the results of this invention match the target data better in both amplitude and phase than conventional contiguous matching techniques.

[0124] like Figure 8 The figure shown is a comparison of the correlation between seismic data A and seismic data B using this embodiment, conventional contiguous matching technology, and seismic data A. Figure 8 In the diagram, the left image shows the similarity coefficient between the imaging results of the original seismic data A and the imaging results of seismic data B; the middle image shows the similarity coefficient between the contiguous imaging result A1 obtained using conventional contiguous matching technology and the imaging result of seismic data B; and the right image shows the similarity coefficient between the contiguous imaging result A2 obtained using this embodiment and the imaging result of seismic data B. Since the similarity coefficient primarily reflects the degree of agreement of phase information, it is determined by… Figure 8 It can be seen that the similarity coefficient increased from 0.5 to 0.72 after using conventional continuous matching technology, but after applying the technology of this embodiment, the similarity coefficient increased to 0.8, achieving a remarkable breakthrough.

[0125] The above describes the matching of data of the same type (towed cable). When matching seismic data A and seismic data B, the process becomes more complex and difficult due to the different acquisition methods, large differences in wavegroup characteristics, small overlap of seismic data, and the fact that they are all located at the boundary of incomplete coverage.

[0126] like Figure 9 and Figure 10 The image shows a comparison between matching seismic data A with seismic data B using the method described in this embodiment, and matching seismic data A with another seismic data set (denoted as C). Figure 9The left-middle image shows the contiguous imaging result from seismic data A to seismic data B when both phase and amplitude operators are applied (denoted as A3). The middle image shows the imaging result of the original seismic data A. The right-middle image shows the contiguous imaging result from seismic data A to seismic data C when both phase and amplitude operators are applied (denoted as A4). Using towed cable data (seismic data B and seismic data C) from regions B and C respectively as targets, contiguous matching was performed on seismic data A from region A. The phase matching results between seismic data A and seismic data B and C are satisfactory. However, the obtained amplitude operators are unstable and exhibit opposite trends; one excessively supplements high frequencies, while the other appears to lose high frequencies. Therefore, it was decided to apply only the phase operator and not the amplitude operator. This application scenario further highlights the advantages of the frequency domain contiguous matching method, as separating the phase and amplitude operators enhances control over the data matching process. In contrast, with the traditional time domain matching method, the phase and amplitude change simultaneously, making the shaping results uncontrollable.

[0127] It should be noted that the above description is merely a preferred embodiment of the present invention and is not intended to limit the present invention. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art can still modify the technical solutions described in the above embodiments or make equivalent substitutions for some of the technical features. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the protection scope of the present invention.

Claims

1. A method for processing contiguous seismic data, characterized in that, Includes the following steps: S1. Denote the two seismic data to be processed as seismic data A and seismic data B. Perform coherent enhancement on the seismic traces included in seismic data A and seismic data B to achieve signal enhancement processing. S2. Perform Fourier transform on each seismic trace of the signal-enhanced seismic data A and seismic data B to transform the data to the frequency domain and separate the phase spectrum and amplitude spectrum in the frequency domain. S3. In the frequency domain, subtract the phase spectrum of seismic data A from the phase spectrum of seismic data B corresponding to the seismic trace to obtain the phase spectrum factor of each seismic trace when shaping seismic data A into seismic data B; divide the amplitude spectrum of seismic data B corresponding to the seismic trace by the amplitude spectrum of seismic data A to obtain the amplitude spectrum factor of each seismic trace when shaping seismic data A into seismic data B. S4. In the frequency domain, perform median filtering or mean filtering smoothing on the phase spectral factor and amplitude spectral factor of each seismic trace when shaping seismic data A to seismic data B. Then, sum and average the phase spectral factor and amplitude spectral factor of each seismic trace to obtain the frequency domain phase factor and frequency domain amplitude factor of seismic data A to seismic data B, and obtain the frequency domain phase operator and frequency domain amplitude operator of seismic data A to seismic data B. The formulas for the frequency domain phase operator and the frequency domain amplitude operator are as follows: ； Among them, X phase (ω) is the frequency-domain phase operator for shaping seismic data A into seismic data B, X amplitude Φ1(ω) is the frequency domain amplitude operator for shaping seismic data A into seismic data B, Φ1(ω) is the final frequency domain phase factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B, and T1(ω) is the final frequency domain amplitude factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B. S5. Perform inverse Fourier transform on the frequency domain phase operator and frequency domain amplitude operator for shaping seismic data A to seismic data B respectively to obtain the time domain phase shaping operator and amplitude shaping operator for shaping seismic data A to seismic data B as the frequency varies. S6. The obtained phase shaping operator and amplitude shaping operator are convolved and applied sequentially to seismic data A to achieve continuous shaping processing from seismic data A to seismic data B.

2. The method for processing seismic data in contiguous patches according to claim 1, characterized in that, In step S1, the process of coherently enhancing the seismic traces of seismic data A and seismic data B is as follows: S11. Select several adjacent seismic traces from seismic data A and seismic data B for stacking, and use the i-th seismic trace on the stacked profile of seismic data A as the basis for stacking. The i-th seismic trace on the stacked profile of seismic data B Centered on the data, L seismic traces are taken on each side. The average value of 2L + 1 seismic traces is taken as the model trace of that seismic trace in seismic data A and seismic data B. Where i = 1, 2, ..., n, n is the total number of seismic traces on the stacked profile; j = 1, 2, ..., l, l is the number of sampling points of the seismic trace. S12. The model traces of seismic data A and seismic data B from step S11 are superimposed again within each time window at different dip angles. The dip angle with the strongest energy is then identified and used as the model trace for that seismic trace in the final seismic data A. And the model trace of that seismic trace in seismic data B. ; S13, transfer the seismic traces of seismic data A And its corresponding model Perform wave mixing and extract the seismic traces from seismic data B. And its corresponding model Perform mixing to obtain the mixing channels of seismic data A and seismic data B; ； ； Where K is the percentage of mixing; S14. Calculate the seismic data A model trace within a time window that slides along the seismic trace. Model trace of seismic data B and corresponding mixing channel , The cross-correlation function and autocorrelation function are used to obtain the weighting function for seismic data A and seismic data B; ； ； Where Lc is half the length of the cross-correlation window; This indicates the mixing channel within the correlation window of seismic data A. The mixing channel within the B-correlation window of the seismic data. This represents the model trace within the correlation window of seismic data A. This represents the model trace within the correlation window of seismic data B; Smoothing is applied to the weighted function of seismic data A and seismic data B: ； Where Ls represents the smoothing radius, This represents the weighting function within the correlation window of seismic data A; This represents the weighting function within the correlation window of the seismic data B; S15. Using the weighting function of the smoothed seismic data A and seismic data B as the weights of the corresponding model traces, apply the weights to the seismic traces to be processed. and Perform weighted summation to find the coherent strengthening path; ； 。 3. The method for processing seismic data in contiguous patches according to claim 2, characterized in that, In step S2, the formula for performing Fourier transform on each seismic trace of the signal-enhanced seismic data A and seismic data B is as follows: ； ； in, Let A be the frequency domain of the i-th seismic trace in seismic data A, and the time domain... correspond, For the frequency domain and time domain of seismic data B, see the i-th seismic trace. Corresponding; ω represents the angular frequency, f is the frequency. It is the amplitude spectrum of the i-th seismic trace in seismic data A. It is the amplitude spectrum of the i-th seismic trace in seismic data B. It is the phase spectrum of the i-th seismic trace in seismic data A; It is the phase spectrum of the i-th seismic trace in seismic data B.

4. The seismic data consolidation processing method according to claim 3, characterized in that, In step S3, the formula for calculating the phase spectral factor of each seismic trace during the shaping of seismic data A into seismic data B is as follows: ； The formula for calculating the amplitude spectral factor of each seismic trace during seismic data A-to-seismic data B shaping is as follows: 。 5. The method for processing seismic data in contiguous patches according to claim 4, characterized in that, In step S4, the size of the filter template is E*E, where 5≤E≤31.

6. The seismic data consolidation processing method according to claim 5, characterized in that, In step S4, the phase spectral factor of each seismic trace is calculated when shaping seismic data A to seismic data B. and amplitude spectrum factor The formula for summing and averaging is: ； ； Where T1(ω) is the final frequency domain amplitude factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B, and Φ1(ω) is the final frequency domain phase factor obtained by summing and averaging all seismic traces when shaping seismic data A into seismic data B.

7. A method for processing seismic data in contiguous patches according to claim 6, characterized in that, In step S5, the formulas for performing inverse Fourier transforms on the frequency domain phase operator and the frequency domain amplitude operator are as follows: ； ； Where, x phase (t) is the time-domain phase shaping operator for shaping seismic data A to seismic data B, x amplitude (t) is the time-domain amplitude shaping operator for shaping seismic data A into seismic data B.

8. A method for processing seismic data in contiguous patches according to claim 7, characterized in that, In step S6, the formula for the convolution of the phase shaping operator and the amplitude shaping operator is as follows: ； in, The seismic data A is the data before the continuous shaping. This refers to the seismic data after it has been shaped and consolidated from seismic data A to seismic data B.

Images