Longitudinal wave and converted wave matching method and system based on inversion

Abstract

The invention provides a longitudinal wave and converted wave matching method and system based on inversion, and belongs to the technical field of oil exploration, and the method comprises the steps: obtaining logging information, a longitudinal wave superposition data body, a longitudinal wave pre-stack gather data body and a converted wave superposition data body of a multi-component earthquake; performing well-seismic calibration on the longitudinal wave superposition data body and the converted wave superposition data body, and determining the time depth of the target stratum in longitudinal waves and converted waves; correcting the converted wave from the converted wave time domain to the longitudinal wave time domain to obtain a converted wave data body; according to the logging information and the longitudinal wave pre-stack gather data body, carrying out pre-stack inversion to obtain transverse wave impedance; according to the logging information and the converted wave data body, carrying out post-stack inversion to obtain shear wave impedance; and determining a time difference according to the shear wave impedance, and matching the converted wave data volume according to the time difference. The problem that longitudinal waves and converted waves are difficult to match due to large energy, frequency and phase differences is solved, the matching precision of the longitudinal waves and the converted waves is improved, and meanwhile accurate matching between marker layers can be achieved.

Description

Technical Field

[0001] The invention belongs to the technical field of petroleum geophysical exploration, and in particular relates to a longitudinal wave and converted wave matching method and system based on inversion. Background Art

[0002] At present, seismic exploration in the field of oil and gas field exploration, development and evaluation is usually a single-component seismic with P-wave excitation and P-wave reception. As the difficulty of exploration continues to increase, multi-component seismic exploration with P-wave excitation and P- and S-wave joint reception has received more and more attention due to the addition of S-wave information. In multi-component seismic, the signal of P-wave excitation and P-wave reception is called PP wave, or P-wave; the signal of P-wave excitation and S-wave reception is called PS wave, or conversion wave.

[0003] Since the propagation path of the converted wave is different from that of the longitudinal wave, the reflected shear wave velocity is different from that of the longitudinal wave, resulting in different propagation times of the longitudinal wave and the converted wave in the same stratum. In the process of multi-component seismic interpretation, the longitudinal wave and the converted wave of the same stratum should be corrected to the same time scale. The usual practice is to compress the converted wave data from the converted wave time domain to the longitudinal wave time domain to achieve matching of the longitudinal and shear wave data. Since the peak on the longitudinal wave data does not necessarily correspond to the peak on the converted wave data, and the frequency and phase of the longitudinal wave and the converted wave are different, and the energy difference is large, it is often difficult to match the longitudinal wave and the converted wave.

[0004] At present, the methods for matching P-waves and converted waves are mainly divided into two categories: one is based on the principle of maximum similarity of reflection event axes of P-waves and converted waves. Since P-waves and converted waves often have obvious differences in reflection characteristics, this type of method has low matching accuracy; the other method is based on matching reflection marker layers. This type of method can only meet the matching of large sets of strata, and cannot accurately match between marker layers. Summary of the invention

[0005] In view of the above problems, the present invention proposes a method and system for matching longitudinal waves and converted waves based on inversion, which solves the problem of large differences in energy, frequency and phase between longitudinal waves and converted waves, improves the matching accuracy of longitudinal waves and converted waves, and has obvious practical significance for multi-component seismic exploration.

[0006] The embodiment of the present invention provides a method for matching longitudinal waves and converted waves based on inversion, comprising:

[0007] Obtain well logging data, multi-component seismic P-wave stack data volume PP, multi-component seismic P-wave pre-stack gather data volume CRP and converted wave stack data volume PS1 in the study area;

[0008] Performing well seismic calibration on the P-wave stacking data volume PP and the converted wave stacking data volume PS1 to determine the time depth of the target layer at the P-wave and the converted wave;

[0009] Based on the longitudinal wave marker layer and the converted wave marker layer, the converted wave is corrected from the converted wave time domain to the longitudinal wave time domain to obtain the converted wave data volume PS2;

[0010] Based on the logging data and the P-wave prestack gather data volume CRP, prestack inversion is performed to obtain the shear wave impedance S1;

[0011] Post-stack inversion is performed based on the logging data and the converted wave data body PS2 to obtain the shear wave impedance S2;

[0012] A time difference is determined based on the shear wave impedances S1 and S2, and a converted wave data volume PS3 is matched based on the time difference.

[0013] Preferably, before correcting the converted wave from the converted wave time domain to the longitudinal wave time domain based on the longitudinal wave marker layer and the converted wave marker layer to obtain the converted wave data volume PS2, the method includes:

[0014] The purpose is to carry out the PP marker layer interpretation of the longitudinal wave stacking data body and the PS1 marker layer interpretation of the converted wave stacking data body.

[0015] Preferably, the logging data includes but is not limited to:

[0016] P-wave velocity curve, S-wave velocity curve, logging density curve and stratification data, P-wave impedance, S-wave impedance.

[0017] Preferably, the performing of well seismic calibration on the P-wave stacking data volume PP and the converted wave stacking data volume PS1; and determining the time depth of the target layer at the P-wave and the converted wave include:

[0018] Performing well seismic calibration on the P-wave stacking data volume PP;

[0019] Among them, the P-wave velocity curve and the logging density curve are multiplied to obtain the P-wave impedance curve, and the P-wave reflection coefficient sequence is obtained through the P-wave impedance curve;

[0020] Extracting a P-wave seismic wavelet from the P-wave stacking data volume PP, and performing a convolution operation on the P-wave seismic wavelet and the P-wave reflection coefficient sequence to obtain a P-wave synthetic record;

[0021] Compare the P-wave composite record with the P-wave near-hole seismic to match the P-wave composite record with the P-wave near-hole seismic to determine the P-wave time-depth relationship and the target layer location.

[0022] Preferably, the method further comprises:

[0023] Performing well seismic calibration on the converted wave stacking data volume PS1;

[0024] Wherein, the incident angle range of the converted wave is determined according to the acquisition of the converted wave superposition data body PS1; and the converted wave reflection coefficient is calculated according to the incident angle range of the converted wave;

[0025] Extracting a converted wave seismic wavelet from the converted wave stacking data volume PS1, performing a convolution operation on the converted wave seismic wavelet and a converted wave reflection coefficient corresponding to the converted wave incident angle range to obtain a converted wave pre-stack gather, and superimposing the converted wave pre-stack gathers to obtain a converted wave synthetic record;

[0026] The converted wave synthetic record is compared with the converted wave near-hole seismic to match the converted wave synthetic record with the converted wave near-hole seismic to determine the converted wave time-depth relationship and the target layer position.

[0027] Preferably, based on the longitudinal wave marker layer and the converted wave marker layer, the converted wave is corrected from the converted wave time domain to the longitudinal wave time domain to obtain the converted wave data body PS2, including:

[0028] Assume that the time when the marker layer is interpreted on the longitudinal wave data is PPhorizon, and the time when the marker layer is interpreted on the converted wave data is PShorizon;

[0029] According to the formula: Calculate the longitudinal and transverse wave velocity ratio data volume

[0030] According to the longitudinal and transverse wave velocity ratio data The time of the converted wave data is converted into longitudinal wave time to obtain a converted wave data body PS2.

[0031] Preferably, the method of performing prestack inversion based on the well logging data and the P-wave prestack gather data body CRP to obtain the shear wave impedance includes:

[0032] Based on the logging data and the P-wave prestack gather data body CRP, the P-wave prestack inversion is carried out to obtain the S-wave impedance body S1;

[0033] Among them, based on the P-wave impedance, S-wave impedance, logging density curve obtained from logging data, and the P-wave marker layer interpretation results, a low-frequency model of P-wave impedance, S-wave impedance, and logging density is established;

[0034] The CRP data volume of the pre-stack longitudinal wave gather is split and stacked to form multiple stacked volumes;

[0035] Perform well-seismic calibration for each stack body, and extract the stack body wavelet of the calibrated stack body;

[0036] The P-wave impedance, S-wave impedance, low-frequency model of logging density, multiple stacks, and stack wavelets corresponding to each stack are used as input quantities, and the P-wave impedance, S-wave impedance body S1, and density body are obtained through pre-stack sparse pulse inversion.

[0037] Preferably, the method further comprises:

[0038] Based on the logging data and the converted wave data body PS2, post-stack inversion is performed to obtain the shear wave impedance body S2;

[0039] Among them, based on the shear wave impedance curve obtained from the logging data and the interpretation results of the P-wave marker layer, a low-frequency model of shear wave impedance is established;

[0040] Perform well-seismic calibration on the converted wave data body PS2 to extract the wavelet of the converted wave data body PS2;

[0041] The low-frequency model of shear wave impedance, the converted wave data volume PS2 and the wavelet of the converted wave data volume PS2 are taken as input, and the shear wave impedance volume S2 is obtained through post-stack sparse pulse inversion.

[0042] Preferably, determining the time difference according to the shear wave impedance, and matching the converted wave data body PS3 according to the time difference, comprises:

[0043] Compare the shear wave impedance bodies S1 and S2, and calculate the time difference between the shear wave impedance bodies S1 and S2;

[0044] Among them, two sliding windows of the same size are set for S1 and S2, and the maximum time range allowed for S2 to move is given;

[0045] The center position of the sliding time window corresponding to S2 is set at the point where the time shift is calculated in the S2 data body; the center position of the sliding time window corresponding to S1 is set at the point where the time shift is calculated in the S1 data body;

[0046] Within the time range in which S2 is allowed to move, the S1 sliding window is moved up and down. The correlation between S1 and S2 in the sliding window is calculated each time the window is slid. The moving time with the highest correlation is recorded as the time shift of the S2 data body at that point.

[0047] Preferably, the method further comprises:

[0048] The time difference between S1 and S2 is applied to the converted wave data volume PS2 to obtain the converted wave data volume PS3 after fine matching.

[0049] Based on the same inventive concept, the second aspect of the present invention further provides a longitudinal wave and converted wave matching system based on inversion, comprising:

[0050] Data acquisition unit, used to acquire well logging data of the study area, P-wave stack data volume PP of multi-component seismic, P-wave pre-stack gather data volume CRP of multi-component seismic, and converted wave stack data volume PS1;

[0051] A well seismic calibration unit is used to perform well seismic calibration on the P-wave stacking data volume PP and the converted wave stacking data volume PS1; determine the time depth of the target layer at the P-wave and the converted wave;

[0052] A correction unit, for correcting the converted wave from the converted wave time domain to the longitudinal wave time domain based on the longitudinal wave marker layer and the converted wave marker layer, to obtain a converted wave data body PS2;

[0053] The prestack inversion unit is used to perform prestack inversion based on the well logging data and the P-wave prestack gather data volume CRP to obtain the shear wave impedance;

[0054] A post-stack inversion unit is used to perform post-stack inversion based on the well logging data and the converted wave data body PS2 to obtain the shear wave impedance;

[0055] The matching unit is used to determine the time difference according to the shear wave impedance and match the converted wave data body PS3 according to the time difference.

[0056] Based on the same inventive concept, the third aspect of the present invention further provides an electronic device, comprising:

[0057] A processor, a communication interface, a memory and a communication bus, wherein the processor, the communication interface and the memory communicate with each other via the communication bus;

[0058] a memory storing a computer program;

[0059] The processor implements the inversion-based longitudinal wave and converted wave matching method when executing the program stored in the memory.

[0060] Based on the same inventive concept, the fourth aspect of the present invention further provides a computer-readable storage medium storing a computer program, which, when executed by a processor, implements an inversion-based longitudinal wave and converted wave matching method.

[0061] Beneficial effects of the present invention:

[0062] The present invention provides a method and system for matching P-wave and converted wave based on inversion, which obtains well logging data, P-wave stacking data body PP of multi-component seismic, P-wave prestack gather data body CRP and converted wave stacking data body PS1; performs well seismic calibration on P-wave stacking data body PP and converted wave stacking data body PS1 to determine the time depth of target layer in P-wave and converted wave; corrects the converted wave from the converted wave time domain to the P-wave time domain based on the P-wave marker layer and the converted wave marker layer to obtain the converted wave data body PS2; performs prestack inversion based on well logging data and P-wave prestack gather data body CRP to obtain the shear wave impedance S1; performs poststack inversion based on well logging data and converted wave data body PS2 to obtain the shear wave impedance S2; determines the time difference based on the shear wave impedances S1 and S2, and matches the converted wave data body PS3 based on the time difference. The problem that P-wave and converted wave are difficult to match due to large differences in energy, frequency and phase is solved, the matching accuracy of P-wave and converted wave is improved, and accurate matching between marker layers can be achieved at the same time.

[0063] Other features and advantages of the present invention will be described in the following description, and partly become obvious from the description, or be understood by implementing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures pointed out in the description and the drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0064] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0065] Figure 1 A flow chart of a method for matching longitudinal waves and converted waves based on inversion according to an embodiment of the present invention;

[0066] Figure 2 This is a longitudinal wave and converted wave well seismic calibration diagram of an embodiment of the present invention;

[0067] Figure 3 It is a schematic diagram of converting the time domain of a wave into the time domain of a longitudinal wave based on a marker layer according to an embodiment of the present invention;

[0068] Figure 4 This is a cross-sectional view of a shear wave impedance body S1 obtained by pre-stack inversion of longitudinal waves in an embodiment of the present invention;

[0069] Figure 5 This is a cross-sectional view of a shear wave impedance body S2 obtained by post-stack inversion of converted waves according to an embodiment of the present invention;

[0070] Figure 6The time difference profile of the shear wave impedance body S1 and S2 in the embodiment of the present invention;

[0071] Figure 7 A comparison diagram of the converted wave data volume PS2 and the finely matched data volume PS3 according to an embodiment of the present invention;

[0072] Figure 8 A schematic diagram of a longitudinal wave and converted wave matching system based on inversion according to an embodiment of the present invention;

[0073] Fig. 9 The figure is a schematic diagram of an electronic device according to an embodiment of the present invention. DETAILED DESCRIPTION

[0074] In order to make the purpose, technical solution and advantages of the embodiments of the present invention clearer, the technical solution in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0075] It should be noted that the terms "first", "second" etc. in the present application are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequential order. It should be understood that the data used in this way can be interchanged in appropriate circumstances, so that the embodiments of the present application described here. In the present application, the orientation or positional relationship indicated by the terms "upper", "lower", "left", "right", "front", "back", "top", "bottom", "inside", "outside", "middle", "vertical", "horizontal", "lateral", "longitudinal" etc. are based on the orientation or positional relationship shown in the accompanying drawings.

[0076] On the one hand, an embodiment of the present invention provides a method for matching longitudinal waves and converted waves based on inversion, see Figure 1 ,include:

[0077] S101: Acquire well logging data of the study area, P-wave stack data volume PP of multi-component seismic, P-wave pre-stack gather data volume CRP of multi-component seismic, and converted wave stack data volume PS1;

[0078] Specifically, the logging data include but are not limited to: P-wave velocity curve, S-wave velocity curve, logging density curve and layering data; P-wave impedance, S-wave impedance. The multi-component seismic data in this embodiment are P-wave stacking data, P-wave prestack gather data and converted wave stacking data processed by prestack time migration.

[0079] S102: Performing well seismic calibration on the P-wave stacking data volume PP and the converted wave stacking data volume PS1; determining the time depth of the target layer at the P-wave and the converted wave;

[0080] Specifically, the seismic calibration is performed on the P-wave stacking data volume PP; specifically, see Figure 2 (Left), the P-wave velocity curve and the logging density curve are multiplied to obtain the P-wave impedance curve, and the P-wave reflection coefficient sequence is obtained through the P-wave impedance curve;

[0081] Extracting a P-wave seismic wavelet from the P-wave stacking data volume PP, and performing a convolution operation on the P-wave seismic wavelet and the P-wave reflection coefficient sequence to obtain a P-wave synthetic record;

[0082] Compare the P-wave composite record with the P-wave near-hole seismic to match the P-wave composite record with the P-wave near-hole seismic to determine the P-wave time-depth relationship and the target layer location.

[0083] Performing well seismic calibration on the converted wave stacking data volume PS1;

[0084] Specifically, see Figure 2 (right), the converted wave incident angle range is determined based on the converted wave stack data volume PS1 acquisition;

[0085] Calculating a converted wave reflection coefficient according to the converted wave incident angle range;

[0086] Extracting a converted wave seismic wavelet from the converted wave stacking data volume PS1, performing a convolution operation on the converted wave seismic wavelet and a converted wave reflection coefficient corresponding to the converted wave incident angle range to obtain a converted wave pre-stack gather, and superimposing the converted wave pre-stack gathers to obtain a converted wave synthetic record;

[0087] The converted wave synthetic record is compared with the converted wave near-hole seismic to match the converted wave synthetic record with the converted wave near-hole seismic to determine the converted wave time-depth relationship and the target layer position.

[0088] The following is an exemplary description of the well seismic calibration for the converted wave stacking data volume PS1.

[0089] For example, the incident angle range of the converted wave is 0-60 degrees, according to the formula:

[0090]

[0091] Calculate the converted wave reflection coefficient in the range of 0-60 degrees. Where θ is the incident angle of the longitudinal wave, is the converted wave reflection angle, v s , are the average velocity of longitudinal waves, the average velocity of transverse waves, and the average density of the medium, Δvs , are the longitudinal wave velocity difference, shear wave velocity difference, and density difference, respectively; γ is the ratio of shear wave to longitudinal wave velocity

[0092] Wavelets are extracted from converted wave seismic data and convolved with the converted wave reflection coefficient within the range of 0-60 degrees to generate converted wave pre-stack gathers, which are then stacked to generate converted wave synthetic records. The converted wave synthetic records are compared with the converted wave wellside seismic data to achieve the best match between the converted wave synthetic records and the converted wave wellside seismic data, and the time-depth relationship and the location of the target layer are determined.

[0093] S103: Based on the longitudinal wave marker layer and the converted wave marker layer, the converted wave is corrected from the converted wave time domain to the longitudinal wave time domain to obtain a converted wave data volume PS2;

[0094] Specifically, it is assumed that the time when the marker layer is interpreted on the longitudinal wave data is PPhorizon, and the time when the marker layer is interpreted on the converted wave data is PShorizon;

[0095] According to the formula: Calculate the longitudinal and transverse wave velocity ratio data volume

[0096] According to the longitudinal and transverse wave velocity ratio data The time of the converted wave data is converted into longitudinal wave time to obtain a converted wave data body PS2.

[0097] Specifically, see Figure 3 (c) Align H1, H2, and H3 interpreted on the PS1 data with H1, H2, and H3 interpreted on the PP data to obtain the converted wave data volume PS2.

[0098] S104: Based on the logging data and the P-wave prestack gather data body CRP, P-wave prestack inversion is performed to obtain the shear wave impedance S1;

[0099] Specifically, in this embodiment, the constrained sparse pulse method is used to carry out the prestack inversion of longitudinal waves to obtain the shear wave impedance body S1. Figure 4 , based on the P-wave impedance, S-wave impedance, logging density curve obtained from logging data, and the P-wave marker layer interpretation results, a low-frequency model of P-wave impedance, S-wave impedance, and logging density is established;

[0100] The CRP pre-stack gather data volume is split into multiple parts, and the parts are stacked to form multiple stacked volumes.

[0101] Perform well-seismic calibration for each stack body, and extract the stack body wavelet of the calibrated stack body;

[0102] The P-wave impedance, S-wave impedance, low-frequency model of logging density, multiple stacks, and stack wavelets corresponding to each stack are used as input quantities, and the P-wave impedance, S-wave impedance body S1, and density body are obtained through pre-stack sparse pulse inversion.

[0103] S105: Perform post-stack inversion based on the logging data and the converted wave data body PS2 to obtain the shear wave impedance S2;

[0104] Specifically, in this embodiment, the constrained sparse pulse method is used to carry out converted wave post-stack inversion to obtain the shear wave impedance body S2, see Figure 5 , based on the logging data and the converted wave data body PS2, the converted wave post-stack inversion is carried out to obtain the shear wave impedance body S2;

[0105] Among them, based on the shear wave impedance curve obtained from the logging data and the interpretation results of the P-wave marker layer, a low-frequency model of shear wave impedance is established;

[0106] Perform well-seismic calibration on the converted wave data body PS2 to extract the wavelet of the converted wave data body PS2;

[0107] The low-frequency model of shear wave impedance, the converted wave data volume PS2 and the wavelet of the converted wave data volume PS2 are taken as input, and the shear wave impedance volume S2 is obtained through post-stack sparse pulse inversion.

[0108] S106: Determine the time difference according to the shear wave impedance, and match the converted wave data body PS3 according to the time difference.

[0109] Specifically, the shear wave impedance bodies S1 and S2 are compared and their time difference is calculated. Specifically, the same sliding time window is set for S1 and S2, and the maximum time range allowed for S2 to move is given; the center position of the sliding time window is set at the point where the time shift is calculated in the S2 data body, and the center of another sliding time window of the same size is set at the same point in the S1 data body; within the maximum time range allowed for S2 to move, the S1 sliding time window is moved up and down, and the correlation between S1 and S2 in the sliding time window is calculated each time it slides; the moving time when the correlation is highest is recorded as the time shift of the point in the S2 data body.

[0110] See also Figure 6 , the time difference between S1 and S2 is applied to the converted wave data volume PS2 to obtain the converted wave data volume PS3 after fine matching. Figure 7 Compared with the converted wave data volume PS2, the converted wave data volume PS3 after fine matching has an obvious time shift at the position indicated by the arrow.

[0111] In some optional embodiments, before correcting the converted wave from the converted wave time domain to the longitudinal wave time domain based on the longitudinal wave marker layer and the converted wave marker layer to obtain the converted wave data volume PS2, the method includes:

[0112] The purpose is to carry out the PP marker layer interpretation of the longitudinal wave stacking data body and the PS1 marker layer interpretation of the converted wave stacking data body.

[0113] Specifically, see Figure 3 (a) and (b) For example: H1, H2, and H3 have strong trough reflections in both P-wave and converted waves and can be used as marker layers. Therefore, the H1, H2, and H3 layers are interpreted on the P-wave PP and converted wave PS1 data, respectively.

[0114] In some optional embodiments, determining the time difference according to the shear wave impedance, and matching the converted wave data body PS3 according to the time difference, comprises:

[0115] Compare the shear wave impedance bodies S1 and S2, and calculate the time difference between the shear wave impedance bodies S1 and S2;

[0116] Set two sliding windows of the same size for S1 and S2, and give the maximum time range within which S2 is allowed to move;

[0117] The center position of the sliding time window corresponding to S2 is set at the point where the time shift is calculated in the S2 data body; the center position of the sliding time window corresponding to S1 is set at the point where the time shift is calculated in the S1 data body;

[0118] Within the time range in which S2 is allowed to move, the S1 sliding window is moved up and down. The correlation between S1 and S2 in the sliding window is calculated each time the window is slid. The moving time with the highest correlation is recorded as the time shift of the S2 data body at that point.

[0119] In some optional embodiments, the method further includes:

[0120] The time difference between S1 and S2 is applied to the converted wave data volume PS2 to obtain the converted wave data volume PS3 after fine matching.

[0121] Based on the same inventive concept, the second aspect of the embodiment of the present invention provides a longitudinal wave and converted wave matching system based on inversion, see Figure 8 ,include:

[0122] Data acquisition unit 71, used to obtain well logging data of the study area, P-wave stack data volume PP of multi-component seismic, P-wave pre-stack gather data volume CRP of multi-component seismic, and converted wave stack data volume PS1;

[0123] A well seismic calibration unit 72 is used to perform well seismic calibration on the P-wave stacking data volume PP and the converted wave stacking data volume PS1 to determine the time depth of the target layer at the P-wave and the converted wave;

[0124] A correction unit 73, for correcting the converted wave from the converted wave time domain to the longitudinal wave time domain based on the longitudinal wave marker layer and the converted wave marker layer, to obtain a converted wave data volume PS2;

[0125] The prestack inversion unit 74 is used to perform prestack inversion based on the well logging data and the P-wave prestack gather data body CRP to obtain the shear wave impedance;

[0126] A post-stack inversion unit 75 is used to perform post-stack inversion based on the logging data and the converted wave data body PS2 to obtain the shear wave impedance;

[0127] The matching unit 76 is used to determine the time difference according to the shear wave impedance, and match the converted wave data body PS3 according to the time difference.

[0128] The present invention provides a method and system for matching P-wave and converted wave based on inversion, which obtains well logging data, P-wave stacking data body PP of multi-component seismic, P-wave prestack gather data body CRP and converted wave stacking data body PS1; performs well seismic calibration on P-wave stacking data body PP and converted wave stacking data body PS1 to determine the time depth of target layer in P-wave and converted wave; corrects the converted wave from the converted wave time domain to the P-wave time domain based on the P-wave marker layer and the converted wave marker layer to obtain the converted wave data body PS2; performs prestack inversion based on well logging data and P-wave prestack gather data body CRP to obtain the shear wave impedance; performs poststack inversion based on well logging data and converted wave data body to obtain the shear wave impedance; determines the time difference based on the shear wave impedance, and matches the converted wave data body PS3 based on the time difference. The problem that P-wave and converted wave are difficult to match due to large differences in energy, frequency and phase is solved, the matching accuracy of P-wave and converted wave is improved, and accurate matching between marker layers can be achieved at the same time.

[0129] Based on the same inventive concept, the third aspect of the embodiment of the present invention provides an electronic device 161, see Fig. 9 , including a processor 164, a communication interface 165, a memory 162 and a communication bus, wherein the processor 164, the communication interface 165 and the memory 162 communicate with each other through the communication bus;

[0130] A memory 162 storing a computer program 163;

[0131] When the processor 164 executes the program stored in the memory 162, the longitudinal wave and converted wave matching method based on inversion is implemented.

[0132] The above communication bus may be a Peripheral Component Interconnect (PCI) bus or an Extended Industry Standard Architecture (EISA) bus, etc. The communication bus may be divided into an address bus, a data bus, a control bus, etc.

[0133] The communication interface 165 is used for communication between the electronic device 161 and other devices.

[0134] The memory 162 may include a random access memory 162 (RAM), or may include a non-volatile memory 162 (non-volatile memory), such as at least one disk memory 162. Optionally, the memory 162 may also be at least one storage device located away from the processor 164.

[0135] The above-mentioned processor 164 can be a general-purpose processor 164, including a central processing unit 164 (CPU), a network processor 164 (NP), etc.; it can also be a digital signal processor 164 (DSP), an application specific integrated circuit (ASIC), a field programmable gate array (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components.

[0136] Based on the same inventive concept, a fourth aspect of an embodiment of the present invention provides a computer-readable storage medium storing a computer program 163 . When the computer program 163 is executed by a processor 164 , a longitudinal wave and converted wave matching method based on inversion is implemented.

[0137] The computer-readable storage medium may be included in the device / apparatus described in the above embodiment; or it may exist independently without being assembled into the device / apparatus. The above computer-readable storage medium carries one or more programs. When the above one or more programs are executed, the longitudinal wave and converted wave matching method based on inversion according to the embodiment of the present disclosure is implemented.

[0138] The above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit them. Although the present application has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for matching longitudinal waves and converted waves based on inversion, characterized in that: include: Obtain well logging data, multi-component seismic P-wave stack data volume PP, multi-component seismic P-wave pre-stack gather data volume CRP and converted wave stack data volume PS1 in the study area; Performing well seismic calibration on the P-wave stacking data volume PP and the converted wave stacking data volume PS1 to determine the time depth of the target layer at the P-wave and the converted wave; Based on the longitudinal wave marker layer and the converted wave marker layer, the converted wave is corrected from the converted wave time domain to the longitudinal wave time domain to obtain the converted wave data volume PS2; Based on the logging data and the P-wave prestack gather data volume CRP, prestack inversion is performed to obtain the shear wave impedance S1; Post-stack inversion is performed based on the logging data and the converted wave data body PS2 to obtain the shear wave impedance S2; A time difference is determined based on the shear wave impedances S1 and S2, and a converted wave data volume PS3 is matched based on the time difference.

2. The method according to claim 1, characterized in that Before the converted wave is corrected from the converted wave time domain to the longitudinal wave time domain based on the longitudinal wave marker layer and the converted wave marker layer to obtain the converted wave data body PS2, it includes: The purpose is to carry out the PP marker layer interpretation of the longitudinal wave stacking data body and the PS1 marker layer interpretation of the converted wave stacking data body.

3. The method according to claim 2, characterized in that The logging data include but are not limited to: P-wave velocity curve, S-wave velocity curve, logging density curve and stratification data, P-wave impedance, S-wave impedance.

4. The method according to claim 1, characterized in that: The well seismic calibration is performed on the P-wave stacking data volume PP and the converted wave stacking data volume PS1; Determine the time depth of the target layer in the longitudinal wave and the converted wave, including: Performing well seismic calibration on the P-wave stacking data volume PP; Among them, the P-wave velocity curve and the logging density curve are multiplied to obtain the P-wave impedance curve, and the P-wave reflection coefficient sequence is obtained through the P-wave impedance curve; Extracting a P-wave seismic wavelet from the P-wave stacking data volume PP, and performing a convolution operation on the P-wave seismic wavelet and the P-wave reflection coefficient sequence to obtain a P-wave synthetic record; Compare the P-wave composite record with the P-wave near-hole seismic to match the P-wave composite record with the P-wave near-hole seismic to determine the P-wave time-depth relationship and the target layer location.

5. The method according to claim 1 or 4, characterized in that: The method further comprises: Performing well seismic calibration on the converted wave stacking data volume PS1; Wherein, the incident angle range of the converted wave is determined according to the acquisition of the converted wave superposition data body PS1; and the converted wave reflection coefficient is calculated according to the incident angle range of the converted wave; Extracting a converted wave seismic wavelet from the converted wave stacking data volume PS1, performing a convolution operation on the converted wave seismic wavelet and a converted wave reflection coefficient corresponding to the converted wave incident angle range to obtain a converted wave pre-stack gather, and superimposing the converted wave pre-stack gathers to obtain a converted wave synthetic record; The converted wave synthetic record is compared with the converted wave near-hole seismic to match the converted wave synthetic record with the converted wave near-hole seismic to determine the converted wave time-depth relationship and the target layer position.

6. The method according to claim 2, characterized in that Based on the longitudinal wave marker layer and the converted wave marker layer, the converted wave is corrected from the converted wave time domain to the longitudinal wave time domain to obtain the converted wave data body PS2, including: Assume that the time when the marker layer is interpreted on the longitudinal wave data is PPhorizon, and the time when the marker layer is interpreted on the converted wave data is PShorizon; According to the formula: Calculate the longitudinal and transverse wave velocity ratio data volume According to the longitudinal and transverse wave velocity ratio data The time of the converted wave data is converted into longitudinal wave time to obtain a converted wave data body PS2.

7. The method according to claim 3, characterized in that The prestack inversion is carried out based on the logging data and the P-wave prestack gather data body CRP to obtain the shear wave impedance, including: Based on the logging data and the P-wave prestack gather data body CRP, the P-wave prestack inversion is carried out to obtain the S-wave impedance body S1; Among them, based on the P-wave impedance, S-wave impedance, logging density curve obtained from logging data, and the P-wave marker layer interpretation results, a low-frequency model of P-wave impedance, S-wave impedance, and logging density is established; The CRP data volume of the pre-stack longitudinal wave gather is split and stacked to form multiple stacked volumes; Perform well-seismic calibration for each stack body, and extract the stack body wavelet of the calibrated stack body; The P-wave impedance, S-wave impedance, low-frequency model of logging density, multiple stacks, and stack wavelets corresponding to each stack are used as input quantities, and the P-wave impedance, S-wave impedance body S1, and density body are obtained through pre-stack sparse pulse inversion.

8. The method according to claim 7, characterized in that The method further comprises: Based on the logging data and the converted wave data body PS2, post-stack inversion is performed to obtain the shear wave impedance body S2; Among them, based on the shear wave impedance curve obtained from the logging data and the interpretation results of the P-wave marker layer, a low-frequency model of shear wave impedance is established; Perform well-seismic calibration on the converted wave data body PS2 to extract the wavelet of the converted wave data body PS2; The low-frequency model of shear wave impedance, the converted wave data volume PS2 and the wavelet of the converted wave data volume PS2 are used as input, and the shear wave impedance volume S2 is obtained through post-stack sparse pulse inversion.

9. The method according to claim 8, characterized in that The determining of the time difference according to the shear wave impedance and matching the converted wave data body PS3 according to the time difference comprises: Compare the shear wave impedance bodies S1 and S2, and calculate the time difference between the shear wave impedance bodies S1 and S2; Among them, two sliding windows of the same size are set for S1 and S2, and the maximum time range allowed for S2 to move is given; The center position of the sliding time window corresponding to S2 is set at the point where the time shift is calculated in the S2 data body; the center position of the sliding time window corresponding to S1 is set at the point where the time shift is calculated in the S1 data body; Within the time range in which S2 is allowed to move, the S1 sliding window is moved up and down. The correlation between S1 and S2 in the sliding window is calculated each time the window is slid. The moving time with the highest correlation is recorded as the time shift of the S2 data body at that point.

10. The method according to claim 9, characterized in that The method further comprises: The time difference between S1 and S2 is applied to the converted wave data volume PS2 to obtain the converted wave data volume PS3 after fine matching.

11. A longitudinal wave and converted wave matching system based on inversion, characterized in that: include: Data acquisition unit, used to acquire well logging data of the study area, P-wave stack data volume PP of multi-component seismic, P-wave pre-stack gather data volume CRP of multi-component seismic, and converted wave stack data volume PS1; A well seismic calibration unit is used to perform well seismic calibration on the P-wave stacking data volume PP and the converted wave stacking data volume PS1; determine the time depth of the target layer at the P-wave and the converted wave; A correction unit, for correcting the converted wave from the converted wave time domain to the longitudinal wave time domain based on the longitudinal wave marker layer and the converted wave marker layer, to obtain a converted wave data body PS2; The prestack inversion unit is used to perform prestack inversion based on the well logging data and the P-wave prestack gather data volume CRP to obtain the shear wave impedance; A post-stack inversion unit is used to perform post-stack inversion based on the well logging data and the converted wave data body PS2 to obtain the shear wave impedance; The matching unit is used to determine the time difference according to the shear wave impedance and match the converted wave data body PS3 according to the time difference.

12. An electronic device, characterized in that: include: A processor, a communication interface, a memory and a communication bus, wherein the processor, the communication interface and the memory communicate with each other via the communication bus; a memory storing a computer program; The processor, when executing the program stored in the memory, implements the inversion-based longitudinal wave and converted wave matching method described in any one of claims 1 to 10.

13. A computer-readable storage medium, characterized in that: A computer program is stored, and when the computer program is executed by a processor, the inversion-based longitudinal wave and converted wave matching method described in any one of claims 1 to 10 is implemented.

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