CO2 migration and storage state monitoring method, system, medium and equipment

Abstract

The invention provides a CO2 migration and storage state monitoring method, system, medium and equipment, and belongs to the field of geophysics comprehensive application. The method comprises the following steps: firstly, respectively calibrating a target interval of CO2 sequestration through different observation systems, and analyzing a difference change range caused before and after CO2 injection through annular VSPs in different directions to obtain a migration boundary of a gas injection well; secondly, processing the ground two-dimensional seismic survey lines before and after CO2 injection by adopting the same processing parameters; and finally, performing qualitative analysis on the states before and after CO2 storage by adopting frequency attribute analysis and impedance inversion results, thereby realizing CO2 migration and storage state monitoring. According to the method, a CO2 monitoring closed loop is formed from collection to processing to explanation by adopting a geophysical monitoring means, and fluid migration and storage states before and after gas injection can be effectively compared by collecting changes of related attributes after reservoir fluid changes.

Description

Technical Field

[0001] The present invention belongs to the field of geophysical comprehensive applications, and specifically relates to a CO2 migration and storage status monitoring method, system, medium and equipment. Background Art

[0002] At present, the developed low permeability reservoirs are mainly driven by water, but they face problems such as low single well production, high injection pressure, low injection capacity, difficulty in replenishing formation energy, and difficulty in establishing an effective displacement system. The final recovery rate is generally about 20%. CO2 has good solubility and strong extraction ability in crude oil, which can greatly reduce the viscosity of crude oil, expand and increase the volume. Multiple contacts with crude oil can reduce interfacial tension, thereby greatly improving the recovery rate of oil reservoirs. At the same time, the injected CO2 can be stored underground on a large scale to achieve efficient CO2 emission reduction. Carbon dioxide storage and oil recovery technology is a new technology that takes into account both economic and environmental benefits. CO2 migration and storage monitoring is the key to the successful implementation of CO2 storage and oil recovery, among which geophysical monitoring technology is the most effective means to monitor CO2 migration and storage status.

[0003] Most of the existing CO2 storage and oil recovery technologies are considered from the perspectives of improving miscibility, reservoir engineering technology, and injection-production engineering technology. Among them, the use of geophysical technology to monitor CO2 migration and storage status plays an irreplaceable role. Summary of the invention

[0004] The purpose of the present invention is to solve the problems existing in the above-mentioned prior art and to provide a method, system, medium and equipment for monitoring the migration and storage status of CO2. The present invention aims to use geophysical monitoring means to compare the fluid migration and storage status before and after gas injection by collecting changes in relevant properties after the reservoir fluid is changed.

[0005] The present invention is achieved through the following technical solutions:

[0006] The first aspect of the present invention provides a method for monitoring CO2 migration and storage status, the method steps are as follows:

[0007] Step 1: VSP observation system layout;

[0008] Step 2: ground two-dimensional seismic line processing;

[0009] Step 3, comparative explanation before and after CO2 storage.

[0010] A further improvement of the present invention is:

[0011] The VSP observation system arrangement in step 1 specifically includes:

[0012] Zero-bias VSP, variable-bias VSP, ground two-dimensional line, and ring VSP were deployed in the area. The changes before and after CO2 injection were found through analysis of seismic profile data collected in two rounds, and the migration range of CO2 was obtained.

[0013] The purpose of zero-bias VSP is to calibrate the main reflection wave groups on the two-dimensional seismic line through the well and the annular VSP imaging, and identify the target layer; an annular VSP observation system is deployed near the gas injection well, and through two-phase observation of the annular VSP, the migration boundary of the gas injection well is obtained according to the difference change range caused by different directions before and after CO2 injection.

[0014] A further improvement of the present invention is:

[0015] The ground two-dimensional seismic line processing in step 2 specifically includes:

[0016] Seismic data before and after CO2 injection are collected, and then the collected seismic data are subjected to gather preprocessing, denoising, deconvolution, static correction, stacking and migration in sequence.

[0017] A further improvement of the present invention is:

[0018] The comparative interpretation before and after CO2 storage in step 3 is specifically: using frequency attribute analysis and impedance inversion results to conduct a qualitative analysis of the state of CO2 before and after storage, thereby realizing CO2 migration and storage state monitoring.

[0019] A further improvement of the present invention is:

[0020] The specific operation of the frequency attribute analysis includes:

[0021] Firstly, time-frequency analysis is performed using the matching pursuit time-frequency decomposition method. The maximum energy frequency detected on the time-frequency profile is taken as the initial attenuation frequency. Then, the 65% and 85% seismic wave energies are calculated, and the energy attenuation gradient in the frequency domain is obtained by fitting. This frequency attenuation gradient is used for oil and gas detection.

[0022] A further improvement of the present invention is:

[0023] The impedance inversion adopts a constrained sparse pulse inversion method.

[0024] A further improvement of the present invention is:

[0025] The objective function of the constrained sparse pulse inversion is:

[0026] J=∑|r i | p +λ q ∑(d i -s i ) q +a2 ∑(t i -z i ) 2

[0027] Where: J is the objective function; r i is the reflection coefficient sampling; λ is the residual weight factor between the actual earthquake and the synthetic earthquake record; d i is the seismic trace data sampling; s i is the synthetic seismic data sampling; a is the trend weight factor, generally a=1; t i The wave impedance trend sampling is defined according to the well data; i is the wave impedance sampling between the maximum and minimum wave impedances constrained by the well; p, q are L-mode factors; generally p=1, q=2; i is the serial number of the seismic sampling point.

[0028] A second aspect of the present invention provides a CO2 migration and storage status monitoring system, comprising:

[0029] Deployment unit, used for VSP observation system deployment;

[0030] Survey line processing unit, used for ground two-dimensional seismic survey line processing;

[0031] The CO2 status monitoring unit is used for comparative interpretation before and after CO2 storage, and to monitor CO2 migration and storage status.

[0032] The third object of the present invention is to provide a computer-readable storage medium, which stores at least one computer-executable program, and when the at least one program is executed by the computer, the computer executes the steps in the CO2 migration and storage status monitoring method as described above.

[0033] A fourth aspect of the present invention provides a computer device, comprising a memory and a processor, wherein the memory stores a computer program, and when the computer program is executed by the processor, the processor executes the steps of the CO2 migration and storage status monitoring method as described above.

[0034] Compared with the prior art, the present invention has the following beneficial effects:

[0035] The present invention monitors CO2 migration and storage status through three steps: VSP (vertical seismic profile) observation system arrangement, ground two-dimensional seismic line processing, and comparative interpretation before and after CO2 storage. First, the target layer sections for CO2 storage are calibrated by different observation systems, and then the differential change range caused by CO2 injection before and after is analyzed by annular VSP in different directions to obtain the migration boundary of the gas injection well; secondly, the ground two-dimensional seismic lines before and after CO2 injection are processed with the same processing parameters to facilitate subsequent comparative analysis; finally, the frequency attribute analysis and impedance inversion results are used to qualitatively analyze the status before and after CO2 storage, thereby realizing CO2 migration and storage status monitoring.

[0036] The present invention forms a CO2 monitoring closed loop from collection to processing to interpretation by adopting geophysical monitoring means. By collecting changes in related properties after the reservoir fluid is changed, the fluid migration and sealing status before and after gas injection can be effectively compared. BRIEF DESCRIPTION OF THE DRAWINGS

[0037] Figure 1 The present invention provides a flow chart of a method for monitoring CO2 migration and storage status;

[0038] Figure 2 It is a schematic diagram of the VSP survey line layout;

[0039] Figure 3 It is the different orientations (277°-300°) of ring 1-VSP, stage II and stage I, and the difference;

[0040] Figure 4a It is the pre-treatment result of gas injection of the ground two-dimensional survey line L2 obtained by using the present invention;

[0041] Figure 4b It is the post-processing result of gas injection of the ground two-dimensional survey line L2 obtained by using the present invention;

[0042] Figure 4c It is the difference of the processing results before and after gas injection of the ground two-dimensional survey line L2 obtained by the present invention;

[0043] Figure 5a It is the frequency attenuation gradient result before gas injection of the ground two-dimensional survey line L2 obtained by the present invention;

[0044] Figure 5b It is the frequency attenuation gradient result after gas injection of the ground two-dimensional survey line L2 obtained by the present invention;

[0045] Figure 6a It is the inversion result before gas injection of the ground two-dimensional survey line L2 obtained by using the present invention;

[0046] Figure 6b It is the inversion result after gas injection of the ground two-dimensional survey line L2 obtained by using the present invention. DETAILED DESCRIPTION

[0047] The present invention is further described in detail below in conjunction with the accompanying drawings:

[0048] [Example 1]

[0049] The embodiment of the present invention provides a method for monitoring CO2 migration and storage status. Figure 1 As shown, the method steps are as follows:

[0050] Step 1: VSP observation system layout:

[0051] Before arranging the VSP (vertical seismic profile) observation system, conduct field surveys of the corresponding blocks to understand the terrain information.

[0052] Zero-bias VSP, variable-bias VSP, ground two-dimensional line (well-ground joint mining), and annular VSP were deployed in the area. The changes before and after CO2 injection were discovered through analysis of seismic profile data collected in two rounds, and the CO2 migration range was obtained.

[0053] The purpose of zero-bias VSP is to calibrate the main reflection wave groups on the two-dimensional seismic line through the well and the annular VSP imaging, and identify the target layer; considering that the gas injection well spreads to the surrounding areas after injection, with a range of more than 200 meters, combined with the effective imaging range, an annular VSP observation system is deployed near the gas injection well. Through two-phase observation of the annular VSP, the migration boundary of the gas injection well is obtained according to the difference change range caused by different directions before and after CO2 injection.

[0054] Step 2: Ground 2D seismic line processing:

[0055] Specific operations include:

[0056] Seismic data before and after CO2 injection are collected, and then the collected seismic data are subjected to gather preprocessing, denoising, deconvolution, static correction, stacking and migration in sequence.

[0057] The collected seismic data are raw shot gathers. To obtain the final profile that can reflect the underground geological structure, a series of processing is required, including gather preprocessing, denoising, deconvolution, static correction, stacking and migration.

[0058] For the seismic data collected in the two phases before and after CO2 injection, the key point is to ensure the consistency of processing parameters.

[0059] The gather preprocessing, denoising, deconvolution, static correction, stacking and migration all adopt existing processing methods, which will not be described in detail here.

[0060] Step 3, explanation of the comparison before and after CO2 storage:

[0061] Specifically: frequency attribute analysis and impedance inversion results are used to conduct qualitative analysis of the status of CO2 before and after storage, thereby realizing CO2 migration and storage status monitoring.

[0062] The specific operation of frequency attribute analysis includes: firstly, time-frequency analysis is performed by matching pursuit time-frequency decomposition method, the maximum energy frequency detected on the time-frequency section is used as the initial attenuation frequency, and then the 65% and 85% seismic wave energies are calculated, and the energy attenuation gradient in the frequency domain is obtained by fitting, and the frequency attenuation gradient is used for oil and gas detection. Generally, the attenuation gradient of oil and gas-bearing strata is large.

[0063] The two phases of ground data of the survey line were compared, the amplitude difference was analyzed, the amplitude difference was used to carry out attribute analysis and elastic parameter inversion, and the effects before and after CO2 injection were compared.

[0064] CO2 oil recovery is a gas drive. When the underground strata contain gas, the frequency and amplitude will change, which can be characterized by frequency-related attributes and impedance results related to the amplitude.

[0065] The frequency attribute uses the attenuation gradient gas-bearing prediction technology. The frequency attenuation of the seismic signal increases due to the presence of oil and gas at the high frequency end, and the frequency attenuation gradient can be used for oil and gas detection. In order to obtain better high-frequency attenuation gradient results, the matching pursuit time-frequency decomposition method is used for time-frequency analysis. The maximum energy frequency detected on the time-frequency section is used as the initial attenuation frequency, and then the 65% and 85% seismic wave energies are calculated to fit the energy attenuation gradient in the frequency domain.

[0066] There are many post-stack impedance inversion methods, and conventional algorithms include colored inversion, spectral inversion, constrained sparse pulse inversion, etc. The present invention adopts the constrained sparse pulse inversion method, which organically combines well data with seismic data, and the inversion result is stable and reliable.

[0067] The minimum error function (objective function) of the constrained sparse pulse inversion is:

[0068] J=∑|r i | p +λ q ∑(d i -s i ) q +a 2 ∑(t i -z i ) 2

[0069] Where: J is the objective function; r i is the reflection coefficient sampling; λ is the residual weight factor between the actual earthquake and the synthetic earthquake record; d i is the seismic trace data sampling; s iis the synthetic seismic data sampling; a is the trend weight factor, generally a=1; t i The wave impedance trend sampling is defined according to the well data; i is the wave impedance sampling between the maximum and minimum wave impedances constrained by the well; p, q are L-module factors; generally, p=1, q=2; i is the serial number of the seismic sampling point; the first item is the sum of the absolute values ​​of the reflection coefficients, the second item is the square of the difference between the actual seismic trace and the synthetic record trace, and the third item is the square of the difference between the defined trend constraint and the wave impedance.

[0070] [Example 2]

[0071] Example Taking a certain study area as an example, the method provided by the present invention is used to monitor the migration and storage status of CO2.

[0072] As described in step 1, the VSP (vertical seismic profile) observation system is arranged: zero-bias VSP, variable-bias VSP, ground two-dimensional line (well-ground joint mining), and annular VSP are arranged in the area. Through two rounds of data collection and analysis, the changes before and after CO2 injection are found, and the CO2 migration range is obtained. The purpose of zero-bias VSP is to calibrate the main reflection wave groups on the two-dimensional seismic survey line through the well and the annular VSP imaging, and identify the target layer; considering that the gas injection well diffuses to the surrounding areas after gas injection, with a range of more than 200 meters, combined with the effective imaging range, an annular VSP observation system is arranged near the gas injection well. Through two phases of observation of the annular VSP, the migration boundary of the gas injection well is obtained according to the difference change range caused by different directions before and after CO2 injection. As Figure 2 As shown in the figure, this is a schematic diagram of the VSP survey line layout in the study area. One zero-bias VSP, three variable-bias VSPs and ground two-dimensional lines (L1, L2, L3 (well-ground joint mining)), and six annular VSPs (C1-C6) are deployed in the area. Through two rounds of data collection and analysis, the changes before and after CO2 injection are found, and the CO2 migration range is obtained. Figure 3 In order to analyze the data of different orientations of Phase II and Phase I VSP survey lines (only 277°-300° are shown) using Ring C1 as an example and compare their differences, the migration boundary of the gas injection well to the far well end is obtained based on the difference change range caused by CO2 injection before and after the two-phase observation of Ring 1-VSP, and the migration boundary of the gas injection well to the near well end is determined by Ring 4-VSP.

[0073] As described in step 2, ground 2D seismic line processing: The acquired seismic data is the original shot gather. To obtain the final profile that can reflect the underground geological structure, a series of processing is required, including gather preprocessing, denoising, deconvolution, static correction, stacking and migration, etc. For the seismic data collected in the two phases before and after CO2 injection, the key point is to ensure the consistency of processing parameters. Figure 4a It is the pre-treatment result of gas injection of the ground two-dimensional survey line L2 obtained by using the present invention; Figure 4bIt is the post-processing result of gas injection of the ground two-dimensional survey line L2 obtained by using the present invention; Figure 4c It is the difference of the processing results before and after gas injection of the ground two-dimensional survey line L2 obtained by the present invention. By comparing the two phases of ground data of survey line L2, it is found that there is an amplitude difference in the target layer, and the amplitude change area coincides with the influence area of ​​the gas injection well. The amplitude difference of the overlying formation is not obvious, indicating that the gas injection has little effect on the overlying layer, and the stability of this layer is good.

[0074] As described in step 3, the comparative interpretation before and after CO2 storage: compare the two phases of ground data of the survey line, analyze the amplitude difference, use the amplitude difference to carry out attribute analysis and elastic parameter inversion, and compare the effects before and after CO2 injection. CO2 flooding is a gas drive, and the frequency and amplitude will change after the underground formation contains gas, which can be characterized by frequency-related attributes and impedance results related to amplitude.

[0075] The frequency attribute uses the attenuation gradient gas-bearing prediction technology. The frequency attenuation of the seismic signal increases due to the presence of oil and gas at the high-frequency end, and the frequency attenuation gradient can be used for oil and gas detection. In order to obtain better high-frequency attenuation gradient results, the matching pursuit time-frequency decomposition method is used for time-frequency analysis. The maximum energy frequency detected on the time-frequency section is used as the initial attenuation frequency, and then the 65% and 85% seismic wave energies are calculated to fit the energy attenuation gradient in the frequency domain. Figure 5a and Figure 5b They are the frequency attenuation gradient results before and after gas injection of the ground two-dimensional survey line L2 obtained by the present invention. It can be seen that after CO2 injection, the gas content in the reservoir causes the high-frequency attenuation to be faster and the gradient to be larger (red represents a large gradient value). The high-frequency attenuation gradient attribute can reflect the CO2 injection situation to a certain extent.

[0076] There are many post-stack impedance inversion methods, and conventional algorithms include colored inversion, spectral inversion, constrained sparse pulse inversion, etc. The present invention adopts the constrained sparse pulse inversion method, which organically combines well data with seismic data, and the inversion result is stable and reliable. Figure 6a and Figure 6b They are the inversion results of the ground two-dimensional survey line L2 before and after gas injection obtained by the present invention. The wave impedance can reflect the underground stratum information. It can be seen that after CO2 injection, the gas content in the reservoir will cause the impedance to decrease. The red color represents the low impedance value. Therefore, the impedance can reflect the CO2 injection situation to a certain extent.

[0077] [Example 3]

[0078] The embodiment of the present invention provides a CO2 migration and storage status monitoring system, including:

[0079] The layout unit is used to layout the VSP observation system and performs the following operations:

[0080] Zero-bias VSP, variable-bias VSP, ground two-dimensional line (well-ground joint mining), and annular VSP were deployed in the area. The changes before and after CO2 injection were discovered through analysis of seismic profile data collected in two rounds, and the CO2 migration range was obtained.

[0081] The purpose of zero-bias VSP is to calibrate the main reflection wave groups on the two-dimensional seismic line through the well and the annular VSP imaging, and identify the target layer; considering that the gas injection well spreads to the surrounding areas after injection, with a range of more than 200 meters, combined with the effective imaging range, an annular VSP observation system is deployed near the gas injection well. Through two-phase observation of the annular VSP, the migration boundary of the gas injection well is obtained according to the difference change range caused by different directions before and after CO2 injection.

[0082] The survey line processing unit is used for ground two-dimensional seismic survey line processing and performs the following operations:

[0083] Specific operations include:

[0084] Seismic data before and after CO2 injection are collected, and then the collected seismic data are subjected to gather preprocessing, denoising, deconvolution, static correction, stacking and migration in sequence.

[0085] The CO2 status monitoring unit is used for comparative interpretation before and after CO2 storage, to monitor CO2 migration and storage status, and to perform the following operations:

[0086] Frequency attribute analysis and impedance inversion results are used to conduct qualitative analysis of the status of CO2 before and after storage, thereby realizing CO2 migration and storage status monitoring.

[0087] The specific operation of frequency attribute analysis includes: firstly, time-frequency analysis is performed by matching pursuit time-frequency decomposition method, the maximum energy frequency detected on the time-frequency section is used as the initial attenuation frequency, and then the 65% and 85% seismic wave energies are calculated, and the energy attenuation gradient in the frequency domain is obtained by fitting, and the frequency attenuation gradient is used for oil and gas detection. Generally, the attenuation gradient of oil and gas-bearing strata is large.

[0088] The present invention adopts a constrained sparse pulse inversion method, and through organically combining well data with seismic data, the inversion result is stable and reliable.

[0089] The minimum error function (objective function) of the constrained sparse pulse inversion is:

[0090] J=∑|r i | p +λ q ∑(d i -s i ) q +a 2 ∑(t i -z i ) 2

[0091] Where: J is the objective function; r i is the reflection coefficient sampling; λ is the residual weight factor between the actual earthquake and the synthetic earthquake record; d i is the seismic trace data sampling; s i is the synthetic seismic data sampling; a is the trend weight factor, generally a=1; t i The wave impedance trend sampling is defined according to the well data; i is the wave impedance sampling between the maximum and minimum wave impedances constrained by the well; p, q are L-module factors; generally, p=1, q=2; i is the serial number of the seismic sampling point; the first item is the sum of the absolute values ​​of the reflection coefficients, the second item is the square of the difference between the actual seismic trace and the synthetic record trace, and the third item is the square of the difference between the defined trend constraint and the wave impedance.

[0092] [Example 4]

[0093] An embodiment of the present invention provides a computer-readable storage medium, which stores at least one computer-executable program. When the at least one program is executed by the computer, the computer executes the steps in the CO2 migration and storage status monitoring method described in Example 1.

[0094] [Example 5]

[0095] An embodiment of the present invention provides a computer device, including a memory and a processor, wherein the memory stores a computer program, and when the computer program is executed by the processor, the processor executes the steps of the CO2 migration and storage status monitoring method as described in Example 1.

[0096] Those skilled in the art can understand that all or part of the processes in the above-mentioned embodiment methods can be completed by instructing the relevant hardware through a computer program, and the program can be stored in a non-volatile computer-readable storage medium. When the program is executed, it can include the processes of the embodiments of the above-mentioned methods. Among them, any reference to memory, storage, database or other media used in the embodiments provided in this application can include non-volatile and / or volatile memory. Non-volatile memory may include read-only memory (ROM), programmable ROM (PROM), electrically programmable ROM (EPROM), electrically erasable programmable ROM (EEPROM) or flash memory. Volatile memory may include random access memory (RAM) or external cache memory. As an illustration and not limitation, RAM is available in many forms, such as static RAM (SRAM), dynamic RAM (DRAM), synchronous DRAM (SDRAM), double data rate SDRAM (DDRSDRAM), enhanced SDRAM (ESDRAM), synchronous link (Synchlink) DRAM (SLDRAM), memory bus (Rambus) direct RAM (RDRAM), direct memory bus dynamic RAM (DRDRAM), and memory bus dynamic RAM (RDRAM).

[0097] The above technical solution is only one implementation mode of the present invention. For those skilled in the art, it is easy to make various types of improvements or modifications based on the principles disclosed in the present invention, and it is not limited to the technical solution described in the above specific embodiments of the present invention. Therefore, the above description is only preferred and does not have a restrictive meaning.

Claims

1. A method for monitoring CO2 migration and storage status, characterized in that: The method steps are as follows: Step 1: VSP observation system layout; Step 2: ground two-dimensional seismic line processing; Step 3, comparative explanation before and after CO2 storage.

2. The CO2 migration and storage status monitoring method according to claim 1, characterized in that: The VSP observation system arrangement in step 1 specifically includes: Zero-bias VSP, variable-bias VSP, ground two-dimensional line, and ring VSP were deployed in the area. The changes before and after CO2 injection were found through analysis of seismic profile data collected in two rounds, and the migration range of CO2 was obtained. The purpose of zero-bias VSP is to calibrate the main reflection wave groups on the two-dimensional seismic line through the well and the annular VSP imaging, and identify the target layer; an annular VSP observation system is deployed near the gas injection well, and through two-phase observation of the annular VSP, the migration boundary of the gas injection well is obtained according to the difference change range caused by different directions before and after CO2 injection.

3. The CO2 migration and storage status monitoring method according to claim 2, characterized in that: The ground two-dimensional seismic line processing in step 2 specifically includes: Seismic data before and after CO2 injection are collected, and then the collected seismic data are subjected to gather preprocessing, denoising, deconvolution, static correction, stacking and migration in sequence.

4. The CO2 migration and storage status monitoring method according to claim 3 is characterized in that: The comparative interpretation before and after CO2 storage in step 3 is specifically: using frequency attribute analysis and impedance inversion results to conduct a qualitative analysis of the state of CO2 before and after storage, thereby realizing CO2 migration and storage state monitoring.

5. The CO2 migration and storage status monitoring method according to claim 4, characterized in that: The specific operations of the frequency attribute analysis include: Firstly, time-frequency analysis is performed using the matching pursuit time-frequency decomposition method. The maximum energy frequency detected on the time-frequency profile is taken as the initial attenuation frequency. Then, the 65% and 85% seismic wave energies are calculated, and the energy attenuation gradient in the frequency domain is obtained by fitting. This frequency attenuation gradient is used for oil and gas detection.

6. The CO2 migration and storage status monitoring method according to claim 4, characterized in that: The impedance inversion adopts a constrained sparse pulse inversion method.

7. The CO2 migration and storage status monitoring method according to claim 6, characterized in that: The objective function of the constrained sparse pulse inversion is: J=∑|r i | p +λ q ∑(d i -s i ) q +a 2 ∑(t i -z i ) 2 Where: J is the objective function; r i is the reflection coefficient sampling; λ is the residual weight factor between the actual earthquake and the synthetic earthquake records; d i is the seismic trace data sampling; s i is the synthetic seismic data sampling; a is the trend weight factor, generally a=1; t i The wave impedance trend sampling is defined according to the well data; i is the wave impedance sampling between the maximum and minimum wave impedances constrained by the well; p, q are L-mode factors; generally p=1, q=2; i is the serial number of the seismic sampling point.

8. A CO2 migration and storage status monitoring system, characterized in that: include: Deployment unit, used for VSP observation system deployment; Survey line processing unit, used for ground two-dimensional seismic survey line processing; The CO2 status monitoring unit is used for comparative interpretation before and after CO2 storage, and to monitor CO2 migration and storage status.

9. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores at least one computer-executable program, and when the at least one program is executed by the computer, the computer executes the steps in the CO2 migration and storage status monitoring method according to any one of claims 1 to 7.

10. A computer device, characterized in that: It comprises a memory and a processor, wherein the memory stores a computer program, and when the computer program is executed by the processor, the processor executes the steps of the CO2 migration and storage status monitoring method according to any one of claims 1 to 7.

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