Seismic data processing method and device, equipment, storage medium and program product

Abstract

The invention relates to a seismic data processing method and device, equipment, a storage medium and a program product, and relates to the technical field of geophysical exploration. The method comprises the following steps: acquiring seismic profile data of a target area; obtaining logging data corresponding to one or more drilling wells in the target area; determining well seismic calibration results corresponding to the one or more drilling wells according to data of the positions of the corresponding drilling wells in the seismic profile data and the logging data; the well-seismic calibration result is used for indicating amplitude data corresponding to the longitudinal wave and the converted shear wave in the synthesis channel and the seismic channel respectively; reconstructing the seismic profile data according to the well seismic calibration results corresponding to the one or more drilling wells; and obtaining a multi-wave fusion data volume of the target area according to the reconstructed seismic section data. When the fusion data volume of the scheme is used for carrying out subsequent depiction, the data of the longitudinal waves and the converted transverse waves do not need to be independently depicted and artificially fused.

Description

Technical Field

[0001] This application relates to the field of geophysical exploration technology, and in particular to a seismic data processing method, apparatus, equipment, storage medium, and program product. Background Technology

[0002] In oil and gas exploration, techniques such as single longitudinal wave exploration and multi-wave exploration can be used to characterize the spatial distribution of oil and gas reservoirs.

[0003] In related technologies, since seismic waves have different abilities to identify different types of strata, seismic data from multiple wave fields can be selected through multi-wave exploration to achieve a detailed characterization of the spatial distribution of oil and gas reservoirs.

[0004] However, the multi-wave exploration method in the above technical solution requires the data of at least two wave fields to be characterized separately and then manually fused, which is inefficient and has low accuracy, and has certain limitations. Summary of the Invention

[0005] This application provides a seismic data processing method, apparatus, equipment, storage medium, and program product, the technical solution of which is as follows.

[0006] According to one aspect of this application, a seismic data processing method is provided, the method comprising:

[0007] Obtain seismic profile data for the target area; the seismic profile data is seismic data obtained through ground seismic exploration, and the seismic profile data includes at least P-wave seismic profile data and converted S-wave seismic profile data;

[0008] Acquire logging data corresponding to one or more drilling wells within the target area; the logging data is formation data obtained through underground drilling; the logging data includes at least P-wave logging data and converted S-wave logging data;

[0009] Based on the data corresponding to the location of the drilled well in the seismic profile data and the well logging data, the well seismic calibration results corresponding to the one or more drilled wells are determined; the well seismic calibration results are used to indicate the amplitude data of P-waves and converted S-waves in the synthetic trace and seismic trace, respectively. The seismic trace is the seismic axis corresponding to the one or more drilled wells in the seismic profile data, the synthetic trace is the seismic axis corresponding to the synthetic data, and the synthetic data is the composite seismic record of the seismic profile data and the well logging data corresponding to the one or more drilled wells;

[0010] The seismic profile data is reconstructed based on the well seismic calibration results corresponding to the one or more drilling wells;

[0011] Based on the reconstructed seismic profile data, a multi-wave fusion data volume for the target area is obtained; the multi-wave fusion data volume is profile data that includes at least the P-wave and the converted S-wave.

[0012] According to one aspect of this application, a seismic data processing apparatus is provided, the apparatus comprising:

[0013] The seismic data acquisition module is used to acquire seismic profile data of the target area; the seismic profile data is seismic data obtained through ground seismic exploration, and the seismic profile data includes at least P-wave seismic profile data and converted S-wave seismic profile data.

[0014] The well logging data acquisition module is used to acquire well logging data corresponding to one or more drilling wells within the target area; the well logging data is formation data obtained through underground drilling; the well logging data includes at least P-wave logging data and converted S-wave logging data.

[0015] The well-seismic calibration module is used to determine the well-seismic calibration result corresponding to one or more drilling wells based on the data corresponding to the location of the drilling well in the seismic profile data and the well logging data. The well-seismic calibration result is used to indicate the amplitude data of the P-wave and converted S-wave in the synthetic trace and seismic trace, respectively. The seismic trace is the seismic axis corresponding to the one or more drilling wells in the seismic profile data, and the synthetic trace is the seismic axis corresponding to the synthetic data. The synthetic data is the composite seismic record of the seismic profile data and the well logging data corresponding to the one or more drilling wells.

[0016] The data reconstruction module is used to reconstruct the seismic profile data based on the well seismic calibration results corresponding to the one or more drilling wells.

[0017] The data acquisition module is used to acquire the multi-wave fusion data volume of the target area based on the reconstructed seismic profile data; the multi-wave fusion data volume is profile data that includes at least the P-wave and the converted S-wave.

[0018] In some embodiments, the data reconstruction module is configured to determine an energy correction factor based on the well seismic calibration results corresponding to the one or more drilling wells; the energy correction factor is used to indicate the energy error of the seismic profile data;

[0019] The data reconstruction module is used to reconstruct the seismic profile data according to the energy correction factor.

[0020] In some embodiments, the data reconstruction module is used to obtain the synthetic trace amplitude and seismic trace amplitude corresponding to the P-wave and the converted S-wave, respectively, based on the well seismic calibration results corresponding to the one or more drilling wells.

[0021] The data reconstruction module is used to obtain the synthetic trace energy and seismic trace energy corresponding to the P-wave and the converted S-wave, respectively, based on the synthetic trace amplitude and the seismic trace amplitude corresponding to the P-wave and the converted S-wave, respectively.

[0022] The data reconstruction module is used to determine the energy correction factor based on the synthetic trace energy and the seismic trace energy corresponding to the P-wave and the converted S-wave, respectively.

[0023] In some embodiments, the data reconstruction module is configured to determine the energy correction factors corresponding to the P-wave seismic profile data and the converted S-wave seismic profile data, respectively, based on the synthetic trace energy and the seismic trace energy corresponding to the P-wave and the converted S-wave, respectively, using an energy correction formula; the energy correction formula is:

[0024]

[0025] Wherein, minε is the error function, α and β are the energy correction factors of the P-wave seismic profile data, γ and η are the energy correction factors of the converted S-wave seismic profile data, and E PP (x,f) represents the seismic trace energy corresponding to the P-wave, E PS (x,f) represents the seismic trace energy corresponding to the converted shear wave. The synthetic channel energy corresponding to the longitudinal wave. The energy of the synthesized channel corresponding to the converted shear wave.

[0026] In some embodiments, the data reconstruction module is used to reconstruct the P-wave seismic profile data of the target area according to the energy correction factor using a P-wave conversion formula; the P-wave conversion formula is:

[0027]

[0028] in, For the reconstructed P-wave seismic profile data, FT -1 The expression represents the inverse Fourier transform, α and β are the energy correction factors of the P-wave seismic profile data, sgn[] is the sign function, and N is the number of seismic record samples. The amplitude corresponding to the P-wave seismic profile data. The amplitude corresponding to the converted shear wave seismic profile data. The frequency corresponding to the P-wave seismic profile data;

[0029] The data reconstruction module is used to reconstruct the converted shear wave seismic profile data of the target area according to the energy correction factor using the converted shear wave conversion formula; the converted shear wave conversion formula is:

[0030]

[0031] in, For the reconstructed transformed shear wave seismic profile data, FT -1 The transform is the inverse Fourier transform, and γ and η are the energy correction factors of the transformed shear wave seismic profile data. The amplitude corresponding to the P-wave seismic profile data. The amplitude corresponding to the converted shear wave seismic profile data. The frequency corresponding to the converted shear wave seismic profile data.

[0032] In some embodiments, the data acquisition module is configured to acquire the multi-wave fused data volume of the target area based on the reconstructed P-wave seismic profile data and the converted S-wave seismic profile data using a fusion formula; the fusion formula is:

[0033]

[0034] Among them, A PP-PS (x,t) represents the multi-wave fusion data volume. For the reconstructed P-wave seismic profile data, This refers to the reconstructed converted shear wave seismic profile data.

[0035] According to another aspect of this application, a computer device is provided, the computer device including a processor and a memory, the memory storing at least one instruction, at least one program, code set or instruction set, the at least one instruction, the at least one program, the code set or instruction set being loaded and executed by the processor to implement the seismic data processing method as described above.

[0036] According to another aspect of this application, a computer-readable storage medium is provided, wherein at least one instruction, at least one program, code set, or instruction set is stored therein, wherein the at least one instruction, the at least one program, the code set, or the instruction set is loaded and executed by a processor to implement the seismic data processing method described above.

[0037] According to another aspect of this application, a computer program product is provided, the computer program product including computer instructions stored in a computer-readable storage medium, wherein a processor reads from the computer-readable storage medium and executes the computer instructions to implement the seismic data processing method described above.

[0038] The technical solutions provided in this application embodiment may have the following beneficial effects:

[0039] The scheme shown in this application embodiment can adjust the amplitude of the P-wave and converted S-wave seismic profile data corresponding to the drilling well based on the P-wave and converted S-wave composite seismic record of the drilling well, thereby reconstructing the P-wave and converted S-wave seismic profile data. Then, the P-wave and converted S-wave data volumes are fused to obtain a fused data volume containing P-wave and converted S-wave highlight information. Using the fused data volume of this scheme for subsequent characterization, it is not necessary to characterize the P-wave and converted S-wave data separately and to manually fuse them. This not only improves the efficiency of characterization results but also improves the accuracy of the characterization results. Attached Figure Description

[0040] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0041] Figure 1 This is a flowchart of an exemplary embodiment of the seismic data processing method provided in this application;

[0042] Figure 2 This is a schematic diagram of well seismic calibration results provided in an exemplary embodiment of this application;

[0043] Figure 3 This is a flowchart of an exemplary embodiment of the seismic data processing method provided in this application;

[0044] Figure 4 This is a schematic diagram of reconstructed data provided in an exemplary embodiment of this application;

[0045] Figure 5 This is a flowchart of a method for sculpting riverbed sand bodies by fusing seismic amplitudes of longitudinal waves and converted transverse waves on land, provided in an exemplary embodiment of this application.

[0046] Figure 6 This is a multi-wave fusion data volume river channel depiction planar effect provided in an exemplary embodiment of this application;

[0047] Figure 7This is a three-dimensional sculpting effect of river sand provided in an exemplary embodiment of this application;

[0048] Figure 8 This is a block diagram illustrating a seismic data processing apparatus according to an exemplary embodiment of this application;

[0049] Figure 9 This is a schematic diagram of the structure of a computer device provided in an exemplary embodiment of this application.

[0050] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application. Detailed Implementation

[0051] To make the objectives, technical solutions, and advantages of this application clearer, the embodiments of this application will be described in further detail below with reference to the accompanying drawings.

[0052] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numbers in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this application. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this application as detailed in the appended claims.

[0053] The terminology used in this disclosure is for the purpose of describing particular embodiments only and is not intended to be limiting of the disclosure. The singular forms “a,” “the,” and “the” as used in this disclosure and the appended claims are also intended to include the plural forms unless the context clearly indicates otherwise. It should also be understood that the term “and / or” as used herein refers to and includes any and all possible combinations of one or more of the associated listed items.

[0054] It should be understood that although the terms first, second, etc., may be used in this disclosure to describe various information, such information should not be limited to these terms. These terms are only used to distinguish information of the same type from one another. For example, a first parameter may also be referred to as a second parameter without departing from the scope of this disclosure, and similarly, a second parameter may also be referred to as a first parameter. Depending on the context, the word "if" as used herein may be interpreted as "when," "when," or "in response to determination."

[0055] The following is a definition of some terms used in this application:

[0056] 1) Single P-wave exploration technique: This is a widely used seismic exploration method that uses only P-wave data for geological structure detection and interpretation during the seismic exploration process. This method typically includes the entire process from seismic data acquisition to processing and interpretation, and it occupies an important position in geological exploration due to its simplicity and efficiency.

[0057] 2) Multiwave exploration technology: This refers to a method in seismic exploration that uses not only P-waves (P waves), but also S-waves (S waves) and converted waves (such as PS waves) to detect geological structures. Multiwave exploration technology can provide more information about underground geological structures, and has unique advantages, especially in identifying fractures, reservoir properties, and rock anisotropy.

[0058] The main difference between this technology and single-wave exploration technology is that land multi-wave exploration technology uses a single source to excite and a three-component detector to receive the data. This allows for the acquisition of three-component wavefield information of underground geological targets, providing the possibility for accurately describing the structural morphology of underground geological bodies, predicting fine fractures, and accurately depicting the spatial distribution of oil and gas reservoirs.

[0059] 3) Seismic exploration: a geophysical exploration method that uses artificially generated seismic waves and records their propagation and reflection characteristics in the underground medium to infer the underground geological structure and reservoir characteristics.

[0060] 4) Underground drilling: refers to the process of creating a hole (drill well) of a certain diameter underground through drilling to explore or exploit underground resources.

[0061] 5) Longitudinal wave (Pressure wave, P-wave): A type of compression wave in which the direction of particle vibration is the same as the direction of wave propagation. P-waves can propagate in solids, liquids, and gases.

[0062] In seismic exploration, P-waves can be generated by ground explosions or other vibration sources. P-waves are the fastest-propagating of all types of seismic waves and can be used to detect geological structures, such as stratigraphic interfaces and faults.

[0063] In underground drilling, P-waves can be generated by acoustic pulses emitted from downhole acoustic transmitters. Downhole acoustic logging determines the sound velocity of the rock by measuring the time difference between the emitted acoustic pulses and the arrival of the sound waves at the well wall, and then infers the physical properties of the rock, such as porosity and rock type.

[0064] 6) Transverse Shear Wave (S-wave): This is a type of shear wave in which the direction of particle vibration is perpendicular to the direction of wave propagation. S-waves can only propagate in solids because there is insufficient rigidity in liquids and gases to support the propagation of shear waves. The propagation speed of S-waves is slower than that of P-waves.

[0065] In seismic exploration, S-waves are also generated by ground motion sources, but since S-waves cannot propagate directly from the source, they are usually formed by the transformation of P-waves when they encounter different medium interfaces; S-waves can be used to obtain information about rock rigidity and structure.

[0066] In underground drilling, dipole acoustic logging tools can be used to generate S-waves; S-waves can help identify formation anisotropy, fracture development, etc.

[0067] 7) Synthetic Seismic Records: The creation of synthetic seismic records is essentially a simplified one-dimensional forward modeling process. By improving the accuracy of synthetic seismic record creation, geological strata can be accurately identified, time-depth relationships can be determined, and an accurate correspondence between well data and seismic data can be established. Specifically, the synthetic seismic record F(t) is the result of the convolution of the seismic wavelet S(t) and the reflection coefficient R(t), as shown in the following formula:

[0068] F(t) = S(t) * R(t)

[0069] The seismic wavelet S(t) can be calculated from seismic profile data, and the reflection coefficient R(t) can be calculated from velocity and density logging curves. Logging curves have high vertical resolution, indicating the properties of the formations surrounding the well, while seismic profile data has good horizontal continuity and a wide range, enabling formation tracking and prediction. Synthetic seismic records can convert the depth domain of logging curves to the time domain of seismic profile data, combining vertical and horizontal axis data to improve the accuracy of stratigraphic boundary determination.

[0070] 8) Pre-stack time migration processing: This refers to the time migration processing performed before seismic data stacking; the process aims to map reflection events in the seismic record from the time domain to the spatial domain to improve the lateral resolution of the seismic image and make the underground geological structure more clearly visible.

[0071] Please refer to Figure 1 This illustration shows a flowchart of a seismic data processing method provided in an exemplary embodiment of this application. The method is executed by a computer device, such as... Figure 1 As shown, the method may include steps 110, 120, 130, 140 and 150.

[0072] Step 110: Obtain seismic profile data for the target area; seismic profile data is seismic data obtained through ground seismic exploration, and includes at least P-wave seismic profile data and converted S-wave seismic profile data.

[0073] The aforementioned seismic profile data refers to the time-series record of subsurface reflected waves (i.e., seismic waves) obtained through seismic exploration. This time-series record can indicate the reflection characteristics of the subsurface medium and thus be used to infer subsurface geological structures. For example, the aforementioned seismic profile data can be represented as a time-seismic wave profile, where the time axis represents the time required for the seismic wave to travel from the surface to the subsurface reflection interface and back to the surface, i.e., the two-way travel time.

[0074] The aforementioned seismic waves can be P-waves, converted S-waves, pure S-waves, etc. Correspondingly, the aforementioned seismic profile data can be P-wave seismic profile data, converted S-wave seismic profile data, pure S-wave seismic profile data, etc.

[0075] Optionally, in order to obtain seismic data with high imaging accuracy, computer equipment can perform pre-stack time migration processing on the seismic data of the target area to obtain pre-stack time migration data of seismic waves in the target area, which can be used as seismic profile data of the target area.

[0076] Step 120: Obtain logging data corresponding to one or more drilling wells within the target area; the logging data is formation data obtained through underground drilling; the logging data includes at least P-wave logging data and converted S-wave logging data.

[0077] The target area mentioned above contains at least one drilling well. The logging data is obtained through measurements performed in the well, including but not limited to logging curves for resistivity, velocity, density, gamma rays, sonic transit time, and detailed information on various geological layers within the well. For example, the logging data can be represented as a depth-logging graph, where the depth axis represents the actual depth of the measurement point within the well.

[0078] Optionally, the aforementioned logging data may include logging curves such as P-wave velocity (Vp), S-wave velocity (Vs), density (Den), and gamma ray (GR). Optionally, the aforementioned logging data may also include geological stratification data. Optionally, the aforementioned logging data may also include logging interpretation results.

[0079] The aforementioned logging data can be P-wave logging data, converted S-wave logging data, pure S-wave logging data, etc.

[0080] Step 130: Based on the data corresponding to the location of the drilling well in the seismic profile data and the logging data, determine the well seismic calibration results corresponding to one or more drilling wells; the well seismic calibration results are used to indicate the amplitude data of P-wave and converted S-wave in the synthetic trace and seismic trace, respectively. The seismic trace is the seismic axis corresponding to one or more drilling wells in the seismic profile data, and the synthetic trace is the seismic axis corresponding to the synthetic data. The synthetic data is the combined seismic record of the seismic profile data and logging data corresponding to one or more drilling wells.

[0081] The location of the drilling well in the aforementioned seismic profile data refers to one or more seismic axes corresponding to one or more drilling wells within the target area in the seismic profile data.

[0082] Optionally, the computer equipment can input the data corresponding to the location of the drilling well in the seismic profile data, as well as the processed data of the well logging data, into the seismic data interpretation software to obtain the above-mentioned composite data output by the seismic data interpretation software, and the above-mentioned well-seismic calibration results.

[0083] The aforementioned well-seismic calibration results refer to the combined well-seismic data obtained by mapping well logging data to seismic profile data, which may include synthetic trace amplitude data and seismic trace amplitude data.

[0084] Please refer to Figure 2 The diagram illustrates a well seismic calibration result provided in an exemplary embodiment of this application. Figure 2 Part (a) in the text is the well seismic calibration result corresponding to the P-wave. Synthetic trace 201 is the seismic axis corresponding to the P-wave synthetic data, and seismic trace 202 is the seismic axis corresponding to a drilling well in the P-wave seismic profile data. Figure 2 Part (b) in the diagram is the well seismic calibration result corresponding to the converted shear wave. Synthetic trace 203 is the seismic axis corresponding to the converted shear wave synthetic data, and seismic trace 204 is the seismic axis corresponding to a drilled well in the converted shear wave seismic profile data.

[0085] Step 140: Reconstruct the seismic profile data based on the well seismic calibration results corresponding to one or more drilling wells.

[0086] Well logging data, obtained through underground drilling, represents direct measurement; seismic profile data, obtained through surface seismic exploration, represents indirect inference. Therefore, well logging data is generally more accurate than seismic profile data. Similarly, synthetic amplitude data is more accurate than seismic trace amplitude data. Thus, by referencing the differences between the seismic trace amplitude data corresponding to the drilled well and the synthetic trace amplitude data, the seismic trace amplitude data corresponding to the drilled well can be corrected, thereby reconstructing the seismic profile data including the drilled well.

[0087] In other words, the aforementioned reconstruction of seismic profile data refers to adjusting the amplitude of the seismic profile data. For example, using the above... Figure 2 Taking part (a) as an example, the computer equipment can reconstruct the P-wave profile data based on the difference between the amplitude data corresponding to the synthetic channel 201 and the seismic channel 202.

[0088] Step 150: Based on the reconstructed seismic profile data, obtain the multi-wave fusion data volume of the target area; the multi-wave fusion data volume is profile data that includes at least P-waves and converted S-waves.

[0089] The aforementioned multi-wave fusion data volume refers to a time-seismic profile containing multiple seismic waves. Optionally, a computer device can perform a product operation on the reconstructed seismic profile data to obtain the aforementioned multi-wave fusion data volume.

[0090] The aforementioned multi-wave fusion data volume includes P-wave bright spot information and converted S-wave bright spot information.

[0091] Afterwards, computer equipment can perform three-dimensional characterization of the stratigraphic structure of the target area based on the multi-wave fusion data volume, and obtain the three-dimensional characterization results of the stratigraphy.

[0092] In summary, the scheme shown in this application, based on the P-wave and converted S-wave synthesized seismic records of the drilling well, can adjust the amplitude of the corresponding P-wave and converted S-wave seismic profile data of the drilling well, thereby reconstructing the P-wave and converted S-wave seismic profile data. Subsequently, the P-wave and converted S-wave data volumes are fused to obtain a fused data volume containing P-wave and converted S-wave highlight information. Using the fused data volume of this scheme for subsequent characterization eliminates the need for separate characterization and manual fusion of P-wave and converted S-wave data, which not only improves the efficiency of characterization results but also enhances the accuracy of the characterization results.

[0093] Please refer to Figure 3 This illustration shows a flowchart of a seismic data processing method provided in an exemplary embodiment of this application. The method is executed by a computer device, such as... Figure 3 As shown, step 140 above can be implemented as steps 140a and 140b.

[0094] Step 140a: Determine the energy correction factor based on the well seismic calibration results corresponding to one or more drilling wells; the energy correction factor is used to indicate the energy error of the seismic profile data.

[0095] Step 140b: Reconstruct the seismic profile data based on the energy correction factor.

[0096] Energy is related to the amplitude and frequency of seismic waves and the properties of the strata, and energy is positively correlated with amplitude. Therefore, the above-mentioned adjustment of the amplitude of seismic profile data can be achieved by adjusting the energy error of the seismic profile data.

[0097] The energy correction factor mentioned above can be used to eliminate the difference between the energy of the seismic profile data and the actual energy; then, the computer equipment can adjust the amplitude of the seismic profile data according to the energy correction factor and reconstruct the seismic profile data.

[0098] Different seismic profiles from different strata correspond to different energy correction factors. Because different strata have varying reflectivity, the amplitude and energy errors in the seismic profiles from different strata will differ.

[0099] This application provides a feasible solution for reconstructing seismic profile data. Based on the relationship between energy and amplitude, an energy correction factor is obtained to reconstruct the amplitude of the seismic profile data, thereby reducing the error of the seismic profile data relative to the real data.

[0100] Based on the above Figure 3 In one possible implementation of the scheme in the illustrated embodiment, step 140a can be implemented as steps 140a1, 140a2, and 140a3.

[0101] Step 140a1: Based on the well seismic calibration results corresponding to one or more drilling wells, obtain the synthetic trace amplitude and seismic trace amplitude corresponding to the P-wave and converted S-wave, respectively.

[0102] Among them, computer equipment can use seismic data interpretation software to read the synthetic trace amplitude of the P-wave at a specified time t from the well seismic calibration results. Seismic trace amplitude A PP (x,t), and the synthetic channel amplitude corresponding to the converted shear wave. Seismic trace amplitude A PS (x,t).

[0103] Step 140a2: Based on the synthetic trace amplitude and seismic trace amplitude corresponding to the P-wave and converted S-wave respectively, obtain the synthetic trace energy and seismic trace energy corresponding to the P-wave and converted S-wave respectively.

[0104] Among them, computer equipment can use Fourier transform to convert the synthetic amplitude of the longitudinal wave into the amplitude of the longitudinal wave. Seismic trace amplitude A PP (x,t), and the synthetic channel amplitude corresponding to the converted shear wave. Seismic trace amplitude A PS (x,t) is converted to the synthesized channel frequency corresponding to the longitudinal wave. Seismic trace frequency F PP (x,f), and the synthesized channel frequency corresponding to the converted shear wave. Seismic trace frequency F PS (x,f); then, according to the frequency energy transformation formula, the synthetic channel energy corresponding to the longitudinal wave is obtained. Earthquake energy E PP (x,f), and the synthesized channel energy corresponding to the converted transverse wave. Earthquake energy E PS (x,f).

[0105] The amplitude A of the seismic trace corresponding to the P-wave PP Taking (x,t) as an example, computer equipment can use the inverse Fourier transform formula. and frequency energy transformation formula Obtain the seismic trace energy E corresponding to the P-wave. PP (x,f).

[0106] Step 140a3: Determine the energy correction factor based on the synthetic trace energy and seismic trace energy corresponding to the P-wave and converted S-wave, respectively.

[0107] The computer equipment can adjust the seismic trace energy corresponding to the P-wave based on the synthetic trace energy of the P-wave; and adjust the seismic trace energy corresponding to the transverse wave based on the seismic trace energy of the P-wave, thereby obtaining the first energy correction factor corresponding to the P-wave seismic profile data.

[0108] Accordingly, the computer equipment can adjust the synthetic trace energy of the converted shear wave based on the synthetic trace energy of the P-wave; and adjust the seismic trace energy of the converted shear wave based on the synthetic trace energy of the converted shear wave, thereby obtaining the second energy correction factor corresponding to the converted shear wave seismic profile data.

[0109] This application's embodiments convert the time-domain amplitude, which is difficult to process and analyze, into the frequency-domain energy, which is easier to analyze. By correcting the error in the frequency-domain energy, the error in the time-domain amplitude is corrected. This solution can reduce the computational difficulty and workload of determining the energy correction factor.

[0110] Based on the solutions shown in the above embodiments of this application, in one possible implementation, step 140a3 can be implemented as follows:

[0111] Based on the synthesized trace energy and seismic trace energy corresponding to P-wave and converted S-wave, respectively, the energy correction factors for P-wave seismic profile data and converted S-wave seismic profile data are determined using the energy correction formula. The energy correction formula is as follows:

[0112]

[0113] Where minε is the error function, α and β are the energy correction factors for P-wave seismic profile data, γ and η are the energy correction factors for converted S-wave seismic profile data, and E PP (x,f) represents the seismic trace energy corresponding to the P-wave, E PS (x,f) represents the seismic trace energy corresponding to the converted shear wave. The composite channel energy corresponding to the longitudinal wave. To convert the synthetic channel energy corresponding to the transverse wave.

[0114] When minε equals 0, the seismic trace energy E corresponding to the P-wave PP (x,f) and the seismic trace energy E corresponding to the converted shear wave PS (x,f), seismic trace energy E corresponding to the P-wave PP (x,f) and the composite energy corresponding to the longitudinal wave Convert the seismic trace energy E corresponding to the shear wave PS (x,f) and the synthesis channel energy corresponding to the converted transverse wave Synthesis energy corresponding to longitudinal waves Synthesis channel energy corresponding to the converted shear wave The closest are the P-wave and the converted wave with the smallest energy difference, and the composite trace and the seismic trace with the smallest energy difference.

[0115] In other words, using at least four seismic profile data and at least one well logging data, equation (1) above can be solved to obtain the values ​​of the four energy correction factors α, β, γ, and η. For example, using the above... Figure 2 For example, the seismic trace data and synthetic trace data corresponding to the four types of sand bodies are shown in Table 1.

[0116] Table 1

[0117]

[0118] Computer equipment can obtain the synthetic trace energy and seismic trace energy corresponding to the longitudinal wave and converted transverse wave of the four sand bodies through Fourier transform and frequency energy transformation formula. Substituting into the above formula (1), four energy correction factors α = 0.23, β = 0.98, γ = 31876.38 and η = 152479.31 are obtained.

[0119] This application provides an energy correction formula for determining the energy correction factor. By using an error function, the energy correction factor can be obtained to reduce the energy difference between P-waves and converted waves, and the energy difference between synthetic traces and seismic traces, so as to accurately adjust the seismic profile data and reduce the error of the reconstructed seismic profile data.

[0120] Based on the solutions shown in the above embodiments of this application, in one possible implementation, step 140b can be implemented as follows:

[0121] The P-wave seismic profile data of the target area is reconstructed using the P-wave transformation formula and based on the energy correction factor. The P-wave transformation formula is as follows:

[0122]

[0123] in, For the reconstructed P-wave seismic profile data, FT -1The expression represents the inverse Fourier transform, where α and β are energy correction factors for the P-wave seismic profile data, sgn[] is the sign function, and N is the number of seismic record samples. The amplitude corresponding to the P-wave seismic profile data. To convert the amplitude corresponding to the shear wave seismic profile data, The frequencies corresponding to the P-wave seismic profile data;

[0124] The converted shear wave seismic profile data of the target area is reconstructed using the converted shear wave conversion formula and based on the energy correction factor. The converted shear wave conversion formula is as follows:

[0125]

[0126] in, For the reconstructed converted shear wave seismic profile data, FT -1 This represents the inverse Fourier transform, where γ and η are the energy correction factors for the transformed shear wave seismic profile data. The amplitude corresponding to the P-wave seismic profile data. To convert the amplitude corresponding to the shear wave seismic profile data, To convert the frequencies corresponding to the shear wave seismic profile data.

[0127] The formula for the inverse Fourier transform is:

[0128]

[0129] in, The amplitudes are the corresponding values ​​for P-wave and converted S-wave seismic profile data.

[0130] In the above formulas (2) and (3), Less than hour, exist equal hour, exist Greater than hour,

[0131] In this embodiment of the application, the computer device can obtain the amplitudes corresponding to the P-wave and converted S-wave seismic profile data through seismic data interpretation software; then, the computer device can obtain the frequencies corresponding to the P-wave and converted S-wave seismic profile data respectively based on the amplitudes corresponding to the P-wave and converted S-wave seismic profile data through Fourier transform and frequency-energy transformation formula.

[0132] Please refer to Figure 4This diagram illustrates reconstructed data provided in an exemplary embodiment of this application. Based on the aforementioned P-wave conversion formula, the reconstructed P-wave seismic profile data of sand body 1 is as follows: Figure 4 As shown in part (a); based on the above converted shear wave conversion formula, the reconstructed converted shear wave seismic profile data of sand body 1 is as follows: Figure 4 As shown in part (b) of the document.

[0133] This application provides a P-wave conversion formula for reconstructing P-wave seismic profile data and a conversion formula for reconstructing converted S-wave seismic profile data. By using a sign function, the amplitudes corresponding to the P-wave seismic profile data and the amplitudes corresponding to the converted S-wave seismic profile data can be compared. Then, by using the energy correction factor and inverse Fourier transform, the P-wave and converted S-wave seismic profile data can be reconstructed, thereby improving the accuracy of the reconstructed seismic profile data.

[0134] Based on the solutions shown in the above embodiments of this application, in one possible implementation, step 150 can be implemented as follows:

[0135] Using a fusion formula, the multi-wave fused data volume of the target area is obtained based on the reconstructed P-wave seismic profile data and the transformed S-wave seismic profile data; the fusion formula is as follows:

[0136]

[0137] Among them, A PP-PS (x,t) represents the multi-wave fusion data volume. For the reconstructed P-wave seismic profile data, This is the reconstructed converted shear wave seismic profile data.

[0138] In other words, the P-wave seismic profile data reconstructed from formula (2) and the converted shear wave seismic profile data reconstructed by formula (3) By performing multiplication operations, a multi-wave fused data volume can be obtained.

[0139] The aforementioned multi-wave fusion data volume includes P-wave bright spot information and converted S-wave bright spot information. For example, the multi-wave fusion data volume of sand body 1, such as... Figure 4 As shown in section (c) of the document.

[0140] This application provides a fusion formula for obtaining multi-wave fusion data volumes. It utilizes product operations to fuse longitudinal wave bright spot information and convert transverse wave bright spot information, thereby reducing the computational difficulty of multi-wave fusion data volumes.

[0141] Tight sandstone gas reservoirs (tight gas for short) belong to the category of unconventional natural gas, and they represent the largest scale of unconventional natural gas development to date. In recent years, exploration and development of tight gas have made rapid progress both theoretically and technologically.

[0142] To support the goal of increasing reserves and production in this field, targeted technical research and applications were conducted using P-wave seismic data, achieving effective breakthroughs in amplitude- and fidelity-preserving processing of seismic data, and channel identification and characterization. However, with the deepening of application and actual drilling, it was found that due to the different physical properties of sandstone, the P-wave velocity of sand bodies varies greatly, resulting in insufficient characterization of sand body boundaries in P-wave seismic data. Previously, based on the difference in P-wave impedance between sandstone and the surrounding mudstone, sandstone was classified into three types of sand bodies: high-impedance sand bodies (impedance higher than the overlying mudstone), medium-impedance sand bodies (impedance close to the overlying mudstone), and low-impedance sand bodies (impedance lower than the overlying mudstone). Especially when sandstone is a medium-impedance sand body, the P-wave velocity of the sandstone is close to that of its surrounding mudstone, resulting in a weak wave peak reflection in the P-wave seismic response. This makes it easily mistaken for a "dark spot" non-sand body and ignored, thus causing incomplete P-wave sand body identification and affecting the effectiveness of sand body identification.

[0143] Land multi-wave exploration technology is an important technique for oil and gas exploration that comprehensively utilizes P-waves and converted S-waves. After more than forty years of development and application, land multi-wave exploration technology has certain advantages in lithology and reservoir identification, and is one of the effective means to improve the accuracy of exploration and development of complex oil and gas reservoirs such as tight and low-permeability reservoirs. The main technical advantages of land multi-wave exploration technology include the following aspects:

[0144] 1) For areas such as gas cloud areas, clastic tight gas reservoirs, carbonate reservoirs, and shale oil and gas reservoirs, P-wave data has the characteristics of low signal-to-noise ratio and weak energy, while converted S-wave information can be used to achieve accurate seismic imaging and reservoir characterization.

[0145] 2) The wavefield of multi-wave seismic exploration data on land can simultaneously obtain P-wave and converted S-wave wavefield information. In addition to accurately extracting P-wave velocity parameters, it can also more accurately obtain S-wave velocity parameters, thereby further extracting accurate reservoir elastic parameters, such as Poisson's ratio, P-wave / S-wave velocity ratio, Young's modulus, brittleness index, etc., which can be used to carry out lithological prediction and reservoir characteristic description work.

[0146] 3) Converted shear waves are essentially shear waves, and are more sensitive to reservoir fractures. They can better solve the difficult problems of quantitatively predicting reservoir fracture development characteristics and fluid detection using shear wave splitting characteristics.

[0147] Therefore, in order to meet the high-precision exploration and development needs of the Shaximiao Formation channel-type tight lithologic gas reservoirs, multi-component seismic data have been collected in the Sichuan Basin in recent years. It is hoped that the advantages of P-waves and converted S-waves can be comprehensively applied to improve the accuracy of sand body boundary characterization, so as to support the exploration and development of tight gas in the Shaximiao Formation.

[0148] In the exploration and development of channel sandstone gas reservoirs, channel boundary delineation is fundamental and crucial. Accurate identification of channel thickness and width is a prerequisite for efficient development of horizontal wells. Currently, both P-wave and converted S-wave methods utilize strong seismic amplitude "bright spots" to delineate the boundaries of channel sand bodies. Based on isochronous stratigraphy, the top and bottom isochronous interfaces of the channel sand bodies are determined. According to the seismic response of the strong amplitude "bright spots" of the channel sand bodies, three-dimensional visualization amplitude detection technology is used to quickly identify the sand bodies and delineate their spatial morphology. This yields two sets of results for P-wave and converted S-wave channel sand body identification. These two sets of results are then merged and edited to determine the final unified channel boundary.

[0149] The specific practices in this related technology are as follows: Based on the analysis of well logging curve data, the well logging response characteristics of the target layer and target body are analyzed, and then combined with P-wave and converted S-wave seismic profiles for synthetic recording and calibration. Then, based on the calibration results, layer interpretation and sand body interpretation are carried out separately. Channel characterization is performed using P-wave and converted S-wave wave "bright spot" seismic information, resulting in two different sets of channel identification results. These two sets of channel identification results are then manually modified, corrected, and merged to finally form a single channel boundary, achieving the goal of unifying the P-wave and converted S-wave boundaries. This approach and process is complex and heavily reliant on human factors; human experience determines the accuracy of channel boundary identification. Furthermore, the repeated manual comparison and fusion of channels is inefficient, severely impacting the demand for efficient exploration and development of tight gas.

[0150] Based on the above analysis, there is an urgent need in terrestrial multi-wave seismic exploration for a method and technical process that can efficiently and accurately solve the problem of joint characterization of channel sand bodies by P-waves and converted S-waves, and quickly identify the boundaries, width, and thickness of channel sand bodies, so as to improve the problems of low efficiency and low accuracy of related technologies.

[0151] The different kinematic and dynamic characteristics of P-waves and converted S-waves lead to varying abilities to identify different types of channel sand bodies. Relying on single-wavefield seismic "bright spots" results in incomplete depiction of channel sand bodies. Furthermore, identifying sand bodies using both wavefields requires two separate depictions, followed by channel boundary modification, fusion, and unification, which is time-consuming, inefficient, and heavily influenced by human factors, no longer meeting the requirements for efficient exploration and development of tight gas. Therefore, this application proposes a method for depicting shallow tight sandstone channel sand bodies by fusing onshore P-wave and converted S-wave seismic amplitudes.

[0152] Specifically, using the composite record calibration results (i.e., the well-seismic calibration results) from at least one well and at least four seismic channels in the study area (i.e., the aforementioned target area), the well-seismic data are combined, and the time-domain seismic signal is transformed into frequency-domain seismic energy through Fourier transform. In the frequency domain, the differences in multi-wave amplitude energy caused by non-vector processing of multi-wave seismic data are eliminated using an energy correction formula. The energy correction factor is obtained when the energy difference between P-wave and converted S-wave is minimized. Then, the time-domain P-wave and converted S-wave seismic records are reconstructed using inverse Fourier transform based on the energy correction factor. The reconstructed P-wave and converted S-wave seismic data volumes are multiplied and fused to obtain a multi-wave fused data volume containing P-wave and converted S-wave "bright spot" information. This multi-wave fused data volume is used to achieve one-time sculpting of river channel sand bodies from multi-wave seismic data, obtaining identification results for channel thickness, width, volume, and area. This effectively improves the accuracy of sand body identification, reduces work efficiency, minimizes the influence of human factors, and lays the foundation for subsequent sand body sweet spot prediction.

[0153] Please refer to Figure 5 This illustrates a flowchart of a method for sculpting riverbed sand bodies using fusion of P-wave and converted S-wave seismic amplitudes, provided in an exemplary embodiment of this application. Figure 5 The diagram shows a flowchart of a method for sculpting riverbed sand bodies by fusing P-wave and converted S-wave seismic amplitudes over land, including the following steps:

[0154] Step 1: Obtain P-wave pre-stack time migration profile data and convert S-wave pre-stack time migration profile data:

[0155] Using seismic data processing tools, pre-stack time migration processing of P-wave and converted S-wave seismic data in the study area was carried out to obtain P-wave (PP) pre-stack time migration profile data and converted S-wave (PS) pre-stack time migration profile data.

[0156] Step 2, Load well logging data:

[0157] Using seismic data interpretation tools, we loaded logging curves, geological stratification data of the target formation, and logging interpretation results from all wells in the study area to clarify the depth location of the target formation on the logging curves.

[0158] The logging curves mainly include P-wave velocity (Vp), S-wave velocity (Vs), density (Den), gamma ray curve (GR), etc.; the geological stratification data of the target formation mainly include formation depth, formation thickness, lithological description, etc.; the logging interpretation results mainly include porosity (Por), volume content (Vsh), water saturation (Sw), etc.

[0159] Step 3: Obtain the composite seismic record of P-waves and converted S-waves:

[0160] Based on the method of creating synthetic seismic records, calibration of P-wave synthetic seismic records and converted S-wave synthetic records of all wells in the study area was carried out to obtain the calibration results of P-wave synthetic records and converted S-wave synthetic records, and to determine the time position of the geological interface of the target strata on the corresponding P-wave and converted S-wave seismic profiles.

[0161] Step 4: Obtain the seismic record amplitude values ​​and composite record amplitude values ​​corresponding to P-waves and converted S-waves of the same geological conditions.

[0162] Based on the calibration results of the P-wave composite record, determine the amplitude value of the P-wave composite record (i.e., composite trace) at a certain time t on the geological target interface. P-wave seismic record (i.e., seismic trace) amplitude value A PP (x,t);

[0163] Based on the calibration results of the converted shear wave synthesizer record, the amplitude values ​​of the converted shear wave synthesizer record (i.e., synthesizer trace) on the geological target interface were determined. Convert the amplitude value A of the shear wave seismic record (i.e., seismic trace). PS (x,t).

[0164] Step 5, solve for the four energy correction factors:

[0165] The amplitude value is converted into a frequency domain energy value by Fourier transform. Then, according to the energy consistency correction formula of longitudinal wave and converted transverse wave, the specific values ​​of four energy correction factors α, β, γ and η are obtained when the energy difference between longitudinal wave and converted transverse wave is minimized.

[0166] Specifically, step 5 can be implemented in the following way:

[0167] 1) By using Fourier transform, the time-domain P-wave seismic amplitude A from step 4 is transformed. PP (x,t) is transformed into frequency and spatial domain signals to obtain F PP (x,f); amplitude of P-wave composite seismic record Transform into frequency domain and spatial domain signals to obtain Converted transverse wave synthetic seismic record amplitude values Transform into frequency domain and spatial domain signals to obtain Convert the amplitude value A of the shear wave seismic data PS (x,t) is transformed into frequency and spatial domain signals to obtain F PS (x,f);

[0168] 2) Using the frequency energy transformation formula, the energy of the four frequency domain seismic signals mentioned above is calculated in the frequency domain to obtain the frequency domain energy E of the P-wave seismic record. PP (x,f), frequency domain energy of longitudinal wave synthesis recording Converted shear wave seismic record frequency domain energy E PS (x,f), frequency domain energy of transverse wave synthesis recording

[0169] 3) Substitute the energy of the four frequency domain data obtained in step 2) into the above formula (1);

[0170] 4) Based on the pre-stack time migration profile data of four longitudinal waves, the converted pre-stack time migration profile data of shear waves, and the logging data of one well, solve the above equation (1) to obtain the values ​​of the four energy correction factors α, β, γ, and η.

[0171] Step 6: Reconstruct the P-wave seismic data volume and the converted wave seismic data volume:

[0172] Based on the α and β energy correction factors obtained in step 5, the time-domain P-wave seismic record is reconstructed. The conversion is performed using the formula (2) above;

[0173] Based on the γ and η energy correction factors obtained in step 5, the time-domain transformed shear wave seismic record is reconstructed. The conversion is performed using the formula (3) above.

[0174] Step 7, Obtain the fused data volume:

[0175] P-wave seismic records reconstructed in step 6 Transverse wave data volume conversion Perform a product operation to obtain fused seismic data volume A, which includes P-wave and converted S-wave bright spot information. PP-PS (x,t) is obtained using the above formula (4).

[0176] Step 8: Obtain the results of multi-wave channel sand body sculpting and channel planar layout:

[0177] Using the fused data volume A obtained in step 7, which contains "bright spots" of P-wave and converted S-wave seismic amplitudes PP-PS (x,t) Perform attribute analysis and optimization.

[0178] Specifically, attribute analysis characterizes the lateral continuity of strata by calculating and extracting features such as seismic waveforms, amplitudes, and temporal and frequency variations. This allows for the identification of faults and fractures, as well as the prediction of reservoirs such as channels, carbonate fracture-cavities, and bioherms. Attribute analysis includes geometric and frequency-based attribute analysis, with key features including curvature, texture, highlights, fluid activity, pre- and post-stack formation absorption coefficients, formation slicing, attribute fusion, single-frequency volumes, spectral decomposition, hydrocarbon detection, and pre- and post-stack formation absorption coefficients. For channel identification, attribute analysis techniques such as spectral decomposition, coherent energy gradient, highlights, and attribute fusion can effectively characterize the spatial distribution of channels. Therefore, attributes characterizing channel sand bodies can be extracted, and the attribute information that best reflects the channel boundary can be selected from multiple attributes for channel boundary delineation.

[0179] Subsequently, the optimized attributes were used to perform 3D characterization of the channel sand bodies, obtaining multi-wave 3D sand body characterization results in one go. This yielded channel parameters such as sand body boundaries, width, thickness, channel development area, and volume, resulting in sand body prediction results. The planar effect of the multi-wave fused data volume channel characterization is shown below. Figure 6 As shown in section (c), the 3D sculpting effect of the river channel sand body is displayed as follows. Figure 7 As shown in section (c) of the document.

[0180] In related technologies, it is necessary to characterize the P-wave data volume and the converted S-wave data volume separately to obtain, as shown below. Figure 6 The longitudinal wave data volume shown in section (a) demonstrates the planar representation of the river channel, and as shown in section (a)... Figure 6 The transformed shear wave data volume shown in section (b) illustrates the river channel depiction planar effect; subsequently, the boundaries are modified, merged, and unified manually. Based on the multi-wave fusion data volume obtained using the above method, the following can be directly obtained: Figure 6 The planar effect of the river channel depiction is shown in section (c). The 3D sculpting effect of the river channel sand body from the P-wave data volume is shown below. Figure 7 As shown in section (a), the 3D sculpting effect of the channel sand body with converted shear waves is displayed as follows. Figure 7 As shown in part (b), Figure 7 Arrow 73 in part (c) contains Figure 7 Arrow 71 in part (a) and Figure 7 The 3D sculpting effect at arrow 72 in part (b); Figure 7 Arrow 76 in part (c) contains Figure 7 Arrow 74 in part (a) and Figure 7 The 3D sculpting effect at arrow 75 in part (b) of the image.

[0181] Compared with related technologies, the beneficial technical effects of the above-mentioned method for sculpting river channel sand bodies by fusing the amplitudes of onshore P-wave and converted S-wave seismic waves include:

[0182] 1) This method establishes a novel approach for characterizing channel sand bodies by fusing the "bright spots" of P-wave and converted S-wave amplitudes. It comprehensively utilizes information from both wavefields: firstly, it leverages the effectiveness of converted S-wave seismic amplitude bright spots in identifying high-impedance and medium-impedance sand bodies to compensate for the insufficient ability of P-waves to identify medium-impedance sand bodies; secondly, it leverages the effectiveness of P-wave seismic amplitude bright spots in identifying high-impedance and low-impedance sand bodies to compensate for the insufficient ability of converted S-waves to identify low-impedance sand bodies. To combine the advantages of both wavefields, seismic records from at least one well and at least four channels in the study area are used to synthesize the records and combine well-seismic data. Fourier transform is used to convert the time-domain seismic signal into frequency-domain seismic energy. In the frequency domain, an energy correction formula is used to eliminate the differences in multi-wave amplitude energy caused by non-vector processing of multi-wave seismic data. The energy correction factor is obtained when the energy difference between P-waves and converted S-waves is minimized. The time-domain P-wave and converted S-wave seismic records are reconstructed using inverse Fourier transform with correction factors. The reconstructed P-wave and converted S-wave data volumes are then multiplied and fused to obtain a multi-wave fused data volume containing "bright spot" information from both P-waves and converted S-waves, thereby highlighting geological targets such as river channels (high energy). This P-wave and converted S-wave amplitude correction method converts conventionally difficult-to-process and analyze time-domain signals into easily analyzable frequency-domain signals. Compared with traditional methods, this application achieves multi-wave energy relationship correction in the frequency domain. The method is reliable in principle, convenient and quick to implement, and overcomes the limitations of existing technologies that only perform multi-wave amplitude level correspondence in the time domain.

[0183] 2) This method utilizes the fused data volume highlighting strong energy from multiple waves, and through attribute analysis and optimization, it delineates the boundary of the channel sand body in one go based on the fused "highlights," effectively establishing a new approach to the integrated delineation of channel sand bodies using terrestrial multi-wave seismic data.

[0184] 3) Compared with traditional methods and techniques, this method is more effective and convenient in its implementation, has a reliable foundation, and has obvious application effects. The effectiveness of multi-wave channel carving is improved by more than 3 times. It can effectively solve the problem of the accuracy and effectiveness of carving the longitudinal wave and converted transverse wave of tight gas channel sand bodies separately in terrestrial multi-wave seismic exploration, reduce the influence of human factors, meet the current demand for efficient exploration and development of tight gas, and improve the promotion and application value of this application.

[0185] Please refer to Figure 8 The diagram illustrates a block diagram of an earthquake data processing apparatus according to an exemplary embodiment of this application. This apparatus can be implemented as all or part of a computer device in hardware or a combination of hardware and software to achieve the above-described... Figure 1 , Figure 3 All or part of the steps in the illustrated embodiments. For example... Figure 8 As shown, the device includes:

[0186] The seismic data acquisition module 801 is used to acquire seismic profile data of the target area. The seismic profile data is seismic data obtained through ground seismic exploration, and the seismic profile data includes at least P-wave seismic profile data and converted S-wave seismic profile data.

[0187] The well logging data acquisition module 802 is used to acquire well logging data corresponding to one or more drilling wells within the target area; the well logging data is formation data obtained through underground drilling; the well logging data includes at least P-wave logging data and converted S-wave logging data;

[0188] The well-seismic calibration module 803 is used to determine the well-seismic calibration results for one or more drilling wells based on the data corresponding to the location of the drilling well in the seismic profile data and the logging data. The well-seismic calibration results are used to indicate the amplitude data of the P-wave and converted S-wave in the synthetic trace and seismic trace, respectively. The seismic trace is the seismic axis corresponding to one or more drilling wells in the seismic profile data, and the synthetic trace is the seismic axis corresponding to the synthetic data. The synthetic data is the composite seismic record of the seismic profile data and logging data corresponding to one or more drilling wells.

[0189] The data reconstruction module 804 is used to reconstruct seismic profile data based on the well seismic calibration results corresponding to one or more drilling wells.

[0190] The data acquisition module 805 is used to acquire the multi-wave fusion data volume of the target area based on the reconstructed seismic profile data; the multi-wave fusion data volume is profile data that includes at least P-waves and converted S-waves.

[0191] In some embodiments, the data reconstruction module is used to determine an energy correction factor based on the well seismic calibration results corresponding to one or more drilling wells; the energy correction factor is used to indicate the energy error of the seismic profile data.

[0192] The data reconstruction module is used to reconstruct seismic profile data based on the energy correction factor.

[0193] In some embodiments, the data reconstruction module is used to obtain the synthetic trace amplitude and seismic trace amplitude corresponding to the P-wave and the converted S-wave, respectively, based on the well seismic calibration results corresponding to one or more drilling wells.

[0194] The data reconstruction module is used to obtain the synthetic trace energy and seismic trace energy corresponding to the P-wave and converted S-wave, respectively, based on the synthetic trace amplitude and seismic trace amplitude corresponding to the P-wave and converted S-wave, respectively.

[0195] The data reconstruction module is used to determine the energy correction factor based on the synthetic trace energy and seismic trace energy corresponding to the P-wave and converted S-wave, respectively.

[0196] In some embodiments, the data reconstruction module is used to determine the energy correction factors corresponding to the P-wave seismic profile data and the converted S-wave seismic profile data, respectively, based on the synthetic trace energy and seismic trace energy corresponding to the P-wave and converted S-wave, respectively, using an energy correction formula; the energy correction formula is as follows:

[0197]

[0198] Where minε is the error function, α and β are the energy correction factors for P-wave seismic profile data, γ and η are the energy correction factors for converted S-wave seismic profile data, and E PP (x,f) represents the seismic trace energy corresponding to the P-wave, E PS (x,f) represents the seismic trace energy corresponding to the converted shear wave. The composite channel energy corresponding to the longitudinal wave. To convert the synthetic channel energy corresponding to the transverse wave.

[0199] In some embodiments, the data reconstruction module is used to reconstruct the P-wave seismic profile data of the target area according to the energy correction factor using the P-wave transformation formula; the P-wave transformation formula is:

[0200]

[0201] in, For the reconstructed P-wave seismic profile data, FT -1 The expression represents the inverse Fourier transform, where α and β are energy correction factors for the P-wave seismic profile data, sgn[] is the sign function, and N is the number of seismic record samples. The amplitude corresponding to the P-wave seismic profile data. The amplitude corresponding to the converted shear wave seismic profile data. The frequencies corresponding to the P-wave seismic profile data;

[0202] The data reconstruction module is used to reconstruct the converted shear wave seismic profile data of the target area using the converted shear wave conversion formula and based on the energy correction factor. The converted shear wave conversion formula is as follows:

[0203]

[0204] in, For the reconstructed converted shear wave seismic profile data, FT -1 This represents the inverse Fourier transform, where γ and η are the energy correction factors for the transformed shear wave seismic profile data. The amplitude corresponding to the P-wave seismic profile data. To convert the amplitude corresponding to the shear wave seismic profile data, To convert the frequencies corresponding to the shear wave seismic profile data.

[0205] In some embodiments, the data acquisition module is used to acquire a multi-wave fused data volume of a target area based on the reconstructed P-wave seismic profile data and the converted S-wave seismic profile data using a fusion formula; the fusion formula is:

[0206]

[0207] Among them, A PP-PS (x,t) represents the multi-wave fusion data volume. For the reconstructed P-wave seismic profile data, This is the reconstructed converted shear wave seismic profile data.

[0208] It should be noted that the device provided in the above embodiments is only illustrated by the division of the above functional modules when implementing its functions. In actual applications, the above functions can be assigned to different functional modules according to actual needs, that is, the content structure of the device can be divided into different functional modules to complete all or part of the functions described above.

[0209] Regarding the apparatus in the above embodiments, the specific manner in which each module performs its operation has been described in detail in the embodiments of the relevant method; the technical effects achieved by each module performing its operation are the same as the technical effects in the embodiments of the relevant method, and will not be elaborated here.

[0210] Please refer to Figure 9 This illustration shows a schematic diagram of the structure of a computer device provided in an exemplary embodiment of this application. The computer device 900 includes a Central Processing Unit (CPU) 901, a system memory 904 including Random Access Memory (RAM) 902 and Read-Only Memory (ROM) 903, and a system bus 905 connecting the system memory 904 and the CPU 901. The computer device 900 also includes a Basic Input / Output System (I / O System) 906 that facilitates information transfer between various devices within the computer, and a mass storage device 907 for storing the operating system 913, application programs 914, and other program modules 915.

[0211] The basic input / output system 906 includes a display 908 for displaying information and an input device 909 for user input, such as a mouse or keyboard. Both the display 908 and the input device 909 are connected to the central processing unit 901 via an input / output controller 910 connected to the system bus 905. The basic input / output system 906 may also include the input / output controller 910 for receiving and processing input from multiple other devices such as a keyboard, mouse, or electronic stylus. Similarly, the input / output controller 910 also provides output to a display screen, printer, or other types of output devices.

[0212] Mass storage device 907 is connected to central processing unit 901 via a mass storage controller (not shown) connected to system bus 905. Mass storage device 907 and its associated computer-readable media provide non-volatile storage for computer device 900. That is, mass storage device 907 may include computer-readable media (not shown) such as hard disk or CD-ROM (Compact Disc Read-Only Memory) drive.

[0213] Without loss of generality, computer-readable media can include computer storage media and communication media. Computer storage media includes volatile and non-volatile, removable and non-removable media implemented using any method or technology for storing information such as computer-readable instructions, data structures, program modules, or other data. Computer storage media includes RAM (Random Access Memory), ROM (Read-Only Memory), EPROM (Erasable Programmable Read-Only Memory), EEPROM (Electrically Erasable Programmable Read-Only Memory), flash memory or other solid-state storage technologies, CD-ROM, DVD (Digital Video Disc) or other optical storage, magnetic tape cassettes, magnetic tape, disk storage, or other magnetic storage devices. Of course, those skilled in the art will recognize that computer storage media are not limited to the above-mentioned types. The system memory 904 and mass storage device 907 described above can be collectively referred to as memory.

[0214] Computer device 900 can be connected to the Internet or other network devices via network interface unit 911 connected to system bus 905.

[0215] The memory also includes one or more programs, which are stored in the memory. The central processing unit 901 implements these programs by executing them. Figure 1 All or some of the steps in the method shown.

[0216] In an exemplary embodiment, a chip is also provided, the chip including programmable logic circuitry and / or program instructions, which, when the chip is run on a computer device, are used to implement all or part of the steps of the methods shown in the above embodiments of this application.

[0217] In an exemplary embodiment, a computer program product is also provided, comprising computer instructions stored in a computer-readable storage medium. A processor of a computer device reads the computer instructions from the computer-readable storage medium and executes the computer instructions to implement all or part of the steps of the methods shown in the above embodiments of this application.

[0218] In an exemplary embodiment, a computer-readable storage medium is also provided, which stores a computer program that is loaded and executed by a processor to implement all or part of the steps of the methods shown in the above embodiments of this application.

[0219] Those skilled in the art will understand that all or part of the steps of the above embodiments can be implemented by hardware or by a program instructing related hardware. The program can be stored in a computer-readable storage medium, such as a read-only memory, a disk, or an optical disk.

[0220] Those skilled in the art will recognize that the functions described in the embodiments of this application in one or more of the above examples can be implemented using hardware, software, firmware, or any combination thereof. When implemented using software, these functions can be stored in a computer-readable medium or transmitted as one or more instructions or code on a computer-readable medium. Computer-readable media include computer storage media and communication media, wherein communication media include any medium that facilitates the transfer of a computer program from one place to another. Storage media can be any available medium that can be accessed by a general-purpose or special-purpose computer.

[0221] The above are merely optional embodiments of this application and are not intended to limit this application. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the protection scope of this application.

Claims

1. A seismic data processing method, characterized in that, The method includes: Obtain seismic profile data for the target area; the seismic profile data is seismic data obtained through ground seismic exploration, and the seismic profile data includes at least P-wave seismic profile data and converted S-wave seismic profile data; Acquire logging data corresponding to one or more drilling wells within the target area; the logging data is formation data obtained through underground drilling; the logging data includes at least P-wave logging data and converted S-wave logging data; Based on the data corresponding to the location of the drilled well in the seismic profile data and the well logging data, the well seismic calibration results corresponding to the one or more drilled wells are determined; the well seismic calibration results are used to indicate the amplitude data of P-waves and converted S-waves in the synthetic trace and seismic trace, respectively. The seismic trace is the seismic axis corresponding to the one or more drilled wells in the seismic profile data, the synthetic trace is the seismic axis corresponding to the synthetic data, and the synthetic data is the composite seismic record of the seismic profile data and the well logging data corresponding to the one or more drilled wells; The seismic profile data is reconstructed based on the well seismic calibration results corresponding to the one or more drilling wells; Based on the reconstructed seismic profile data, a multi-wave fusion data volume for the target area is obtained; the multi-wave fusion data volume is profile data that includes at least the P-wave and the converted S-wave.

2. The method according to claim 1, characterized in that, The process of reconstructing the seismic profile data based on the well seismic calibration results corresponding to the one or more drilling wells includes: Based on the well seismic calibration results corresponding to the one or more drilling wells, an energy correction factor is determined; the energy correction factor is used to indicate the energy error of the seismic profile data. The seismic profile data are reconstructed based on the energy correction factor.

3. The method according to claim 2, characterized in that, The step of determining the energy correction factor based on the well seismic calibration results corresponding to the one or more drilling wells includes: Based on the well seismic calibration results corresponding to the one or more drilling wells, obtain the synthetic trace amplitude and seismic trace amplitude corresponding to the P-wave and the converted S-wave, respectively; Based on the synthetic trace amplitude and seismic trace amplitude corresponding to the P-wave and the converted S-wave, respectively, the synthetic trace energy and seismic trace energy corresponding to the P-wave and the converted S-wave, respectively, are obtained; The energy correction factor is determined based on the synthetic trace energy and the seismic trace energy corresponding to the P-wave and the converted S-wave, respectively.

4. The method according to claim 3, characterized in that, The step of determining the energy correction factor based on the synthetic trace energy and the seismic trace energy corresponding to the P-wave and the converted S-wave, respectively, includes: Using an energy correction formula, the energy correction factors corresponding to the P-wave seismic profile data and the converted S-wave seismic profile data are determined based on the synthesized trace energy and the seismic trace energy corresponding to the P-wave and the converted S-wave, respectively. The energy correction formula is as follows: Wherein, minε is the error function, α and β are the energy correction factors of the P-wave seismic profile data, γ and η are the energy correction factors of the converted S-wave seismic profile data, and E PP (x, f) represents the seismic trace energy corresponding to the P-wave, E PS (x, f) represents the seismic trace energy corresponding to the converted shear wave. The synthetic channel energy corresponding to the longitudinal wave. The energy of the synthesized channel corresponding to the converted shear wave.

5. The method according to any one of claims 2 to 4, characterized in that, The process of reconstructing the seismic profile data based on the energy correction factor includes: The P-wave seismic profile data of the target area are reconstructed using the P-wave conversion formula and the energy correction factor; the P-wave conversion formula is as follows: in, For the reconstructed P-wave seismic profile data, FT -1 The expression represents the inverse Fourier transform, α and β are the energy correction factors of the P-wave seismic profile data, sgn[] is the sign function, and N is the number of seismic record samples. The amplitude corresponding to the P-wave seismic profile data. The amplitude corresponding to the converted shear wave seismic profile data. The frequency corresponding to the P-wave seismic profile data; The converted shear wave seismic profile data of the target area are reconstructed using the converted shear wave conversion formula and the energy correction factor; the converted shear wave conversion formula is: in, For the reconstructed transformed shear wave seismic profile data, FT -1 The transform is the inverse Fourier transform, and γ and η are the energy correction factors of the transformed shear wave seismic profile data. The amplitude corresponding to the P-wave seismic profile data. The amplitude corresponding to the converted shear wave seismic profile data. The frequency corresponding to the converted shear wave seismic profile data.

6. The method according to claim 1, characterized in that, The step of obtaining the multi-wave fusion data volume of the target area based on the reconstructed seismic profile data includes: Using a fusion formula, the multi-wave fused data volume of the target area is obtained based on the reconstructed P-wave seismic profile data and the converted S-wave seismic profile data; the fusion formula is: Among them, A PP-PS (x, t) represents the multi-wave fusion data volume. For the reconstructed P-wave seismic profile data, This refers to the reconstructed converted shear wave seismic profile data.

7. A seismic data processing device, characterized in that, The device includes: The seismic data acquisition module is used to acquire seismic profile data of the target area; the seismic profile data is seismic data obtained through ground seismic exploration, and the seismic profile data includes at least P-wave seismic profile data and converted S-wave seismic profile data. The well logging data acquisition module is used to acquire well logging data corresponding to one or more drilling wells within the target area; the well logging data is formation data obtained through underground drilling; the well logging data includes at least P-wave logging data and converted S-wave logging data. The well-seismic calibration module is used to determine the well-seismic calibration result corresponding to one or more drilling wells based on the data corresponding to the location of the drilling well in the seismic profile data and the well logging data. The well-seismic calibration result is used to indicate the amplitude data of the P-wave and converted S-wave in the synthetic trace and seismic trace, respectively. The seismic trace is the seismic axis corresponding to the one or more drilling wells in the seismic profile data, and the synthetic trace is the seismic axis corresponding to the synthetic data. The synthetic data is the composite seismic record of the seismic profile data and the well logging data corresponding to the one or more drilling wells. The data reconstruction module is used to reconstruct the seismic profile data based on the well seismic calibration results corresponding to the one or more drilling wells. The data acquisition module is used to acquire the multi-wave fusion data volume of the target area based on the reconstructed seismic profile data; the multi-wave fusion data volume is profile data that includes at least the P-wave and the converted S-wave.

8. A computer device, characterized in that, The computer device includes a processor and a memory, the memory storing at least one computer instruction, which is loaded and executed by the processor to implement the seismic data processing method as described in any one of claims 1 to 6.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores at least one computer instruction, which is loaded and executed by a processor to implement the seismic data processing method as described in any one of claims 1 to 6.

10. A computer program product, characterized in that, The computer program product includes computer instructions stored in a computer-readable storage medium; the computer instructions are read and executed by a processor of a computer device to implement the seismic data processing method as described in any one of claims 1 to 6.

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