CN113156511B - Method and device for matching well cannon and controllable seismic source mixed acquisition seismic data - Google Patents
Method and device for matching well cannon and controllable seismic source mixed acquisition seismic data Download PDFInfo
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- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
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Abstract
The embodiment of the invention provides a method and a device for matching seismic data acquired by mixing a well gun and a controllable seismic source, wherein the method comprises the following steps: adjusting the controllable source record and the well cannon record in the seismic data to the same energy level; extracting a well gun record and a controllable seismic source record from seismic data, and performing minimum phasing on the controllable seismic source record to obtain a controllable seismic source record after phase conversion; denoising the controlled source record and the well cannon record after phase conversion; performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record; the phase of the controllable seismic source record after longitudinal energy compensation is adjusted to be a mixed phase; superposing the controllable seismic source record with the mixed phase and the well cannon record subjected to longitudinal energy compensation to obtain superposition data; and eliminating the time difference between the controllable source record and the well gun record in the superposition data. The scheme realizes a matching method which is more comprehensive in consideration and has stronger adaptability to the well-seismic combined acquisition data with low signal-to-noise ratio.
Description
Technical Field
The invention relates to the technical field of seismic data processing, in particular to a method and a device for matching seismic data acquired by mixing a well gun and a controllable seismic source.
Background
The explosive source well gun excitation mode used in the seismic data acquisition process cannot be constructed in densely populated towns, the environment can be damaged to a certain extent, the environment is polluted, and the efficient acquisition cannot be realized. However, the controllable seismic source cannot be constructed in areas such as mountain areas due to the limitation of ground surface conditions, so that a hybrid acquisition mode of a well cannon and the controllable seismic source is generated.
The most critical and fundamental processing links in the well-seismic data joint processing are well-seismic data matching. It is conventional practice to minimize the phasing of the vibroseis recordings and match the energy levels of the two. For the data with higher signal-to-noise ratio, the method is feasible, but for the data with lower signal-to-noise ratio, the method is not applicable, and the well shock data acquired by mixing the well cannon and the controllable source belongs to the data with lower signal-to-noise ratio.
Disclosure of Invention
The embodiment of the invention provides a method for matching well cannon and controllable earthquake focus mixed acquisition seismic data, which aims to solve the technical problem that the matching method in the prior art is not suitable for well cannon and controllable earthquake focus mixed acquisition well earthquake data. The method comprises the following steps:
adjusting the controllable source record and the well cannon record in the seismic data to the same energy level;
Extracting a wellgun record and a controllable source record from the seismic data, and performing minimum phasing on the controllable source record to obtain the controllable source record after phase conversion;
Denoising the controlled source record and the well cannon record after phase conversion;
performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record;
adjusting the phase of the controllable seismic source record after longitudinal energy compensation to be a mixed phase;
superposing the controllable seismic source record with the mixed phase and the well cannon record subjected to longitudinal energy compensation to obtain superposition data;
and eliminating the time difference between the controllable source record and the well cannon record in the superposition data.
The embodiment of the invention also provides a device for matching the well cannon and the seismic data acquired by mixing the controllable seismic sources, so as to solve the technical problem that the matching method in the prior art is not suitable for the well cannon and the seismic data acquired by mixing the controllable seismic sources.
The device comprises:
The energy adjustment module is used for adjusting the controllable source record and the well cannon record in the seismic data to the same energy level;
The phase conversion module is used for extracting a wellgun record and a controllable source record from the seismic data, and performing minimum phase minimization on the controllable source record to obtain the controllable source record after phase conversion;
The denoising module is used for denoising the controlled source record and the well cannon record after the phase conversion;
The energy compensation module is used for carrying out longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record;
the phase adjustment module is used for adjusting the phase of the controllable seismic source record after longitudinal energy compensation to be a mixed phase;
the data superposition module is used for superposing the controllable seismic source record of the mixed phase and the well cannon record after longitudinal energy compensation to obtain superposition data;
and the time difference eliminating module is used for eliminating the time difference between the controllable source record and the well cannon record in the superposition data.
The embodiment of the invention also provides computer equipment, which comprises a memory, a processor and a computer program stored on the memory and capable of running on the processor, wherein the processor realizes the matching method of any well cannon and controllable seismic source mixed acquisition seismic data when executing the computer program so as to solve the technical problem that the matching method in the prior art is not suitable for well cannon and controllable seismic source mixed acquisition well seismic data.
The embodiment of the invention also provides a computer readable storage medium which stores a computer program for executing the matching method of the seismic data acquired by mixing the well cannon and the controllable seismic source, so as to solve the technical problem that the matching method in the prior art is not suitable for the well seismic data acquired by mixing the well cannon and the controllable seismic source.
In the embodiment of the invention, the controllable focus record and the wellgun record in the seismic data are regulated to the same energy level, the influence of the energy level on matching is considered, the wellgun record and the controllable focus record are extracted from the seismic data, the controllable focus record is subjected to minimum phasing, the controllable focus record after phase conversion is obtained, the controllable focus record and the wellgun record after phase conversion are denoised, and the influence of noise on matching is considered; performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record, namely considering the influence of the longitudinal attenuation degree on matching, and adjusting the phase of the vibroseis record after the longitudinal energy compensation to be a mixed phase, so that the unmixed phases of the vibroseis record and the wellgun record are realized, and considering the influence of the phase on matching; further, overlapping the controllable seismic source record with the mixed phase and the well cannon record subjected to longitudinal energy compensation to obtain overlapped data; and finally, eliminating the time difference between the controllable seismic source record and the well cannon record in the superimposed data, taking the influence of the time difference on matching into consideration, realizing a matching method which is more comprehensive in consideration and has stronger adaptability to well-seismic combined acquisition data with low signal-to-noise ratio, and being beneficial to laying a foundation for improving the imaging quality of the data.
Drawings
The accompanying drawings, which are included to provide a further understanding of the application and are incorporated in and constitute a part of this specification, illustrate and together with the description serve to explain the application. In the drawings:
FIG. 1 is a flow chart of a method for matching seismic data acquired by mixing a well cannon and a vibroseis provided in an embodiment of the present invention;
FIG. 2 is a schematic diagram of a method for matching seismic data acquired by mixing the wellcannon and the controllable seismic source according to an embodiment of the present invention;
FIG. 3 is a block diagram of a computer device according to an embodiment of the present invention;
Fig. 4 is a block diagram of a device for matching seismic data acquired by mixing a well gun and a controllable seismic source according to an embodiment of the present invention.
Detailed Description
The present invention will be described in further detail with reference to the following embodiments and the accompanying drawings, in order to make the objects, technical solutions and advantages of the present invention more apparent. The exemplary embodiments of the present invention and the descriptions thereof are used herein to explain the present invention, but are not intended to limit the invention.
The inventor of the present application has found through a great deal of research that the following differences exist between the wellgun record and the controllable source record: the energy of the vibroseis and wellcannon recordings differ by several orders of magnitude. GeoEast processing software well cannon source type road head mark is 1, statistics whole cannon root mean square energy is 0.2, controllable source type road head is 4, statistics whole cannon root mean square energy is 5 x 108, and difference is hundred million times. The controllable seismic source record and the well cannon record are inconsistent and cannot be overlapped in phase. The vibroseis record is zero phase and the wellcannon record is a mixed phase. The main noise types of the vibroseis and wellgun recordings are different. The energy attenuation degree in the longitudinal direction of the controllable source record is different from that of the well cannon record. Based on the factors, the application provides the matching method of the seismic data acquired by mixing the well cannon and the controllable seismic source, so that the in-phase superposition of the controllable seismic source record and the well cannon record can be better ensured, and the imaging effect of the well seismic combined acquisition data is improved.
In an embodiment of the present invention, a method for matching seismic data acquired by mixing a wellgun and a controllable seismic source is provided, as shown in fig. 1, where the method includes:
Step 102: adjusting the controllable source record and the well cannon record in the seismic data to the same energy level;
step 104: extracting a wellgun record and a controllable source record from the seismic data, and performing minimum phasing on the controllable source record to obtain the controllable source record after phase conversion;
step 106: denoising the controlled source record and the well cannon record after phase conversion;
Step 108: performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record;
step 110: adjusting the phase of the controllable seismic source record after longitudinal energy compensation to be a mixed phase;
Step 112: superposing the controllable seismic source record with the mixed phase and the well cannon record subjected to longitudinal energy compensation to obtain superposition data;
step 114: and eliminating the time difference between the controllable source record and the well cannon record in the superposition data.
As can be seen from the flow shown in fig. 1, in the embodiment of the present invention, it is proposed to adjust the vibroseis record and the wellgun record in the seismic data to the same energy level, and consider the influence of the energy level on the matching, then extract the wellgun record and the vibroseis record from the seismic data, and perform minimum phasing on the vibroseis record to obtain the vibroseis record after phase conversion, and further perform denoising on the vibroseis record and the wellgun record after phase conversion, and consider the influence of noise on the matching; performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record, namely considering the influence of the longitudinal attenuation degree on matching, and adjusting the phase of the vibroseis record after the longitudinal energy compensation to be a mixed phase, so that the unmixed phases of the vibroseis record and the wellgun record are realized, and considering the influence of the phase on matching; further, overlapping the controllable seismic source record with the mixed phase and the well cannon record subjected to longitudinal energy compensation to obtain overlapped data; and finally, eliminating the time difference between the controllable seismic source record and the well cannon record in the superimposed data, taking the influence of the time difference on matching into consideration, realizing a matching method which is more comprehensive in consideration and has stronger adaptability to well-seismic combined acquisition data with low signal-to-noise ratio, and being beneficial to laying a foundation for improving the imaging quality of the data.
In the specific implementation, the controllable source record and the well shot record in the seismic data are adjusted to the same energy level, specifically, the acquired longitudinal wave single shot data of the whole work area can be subjected to single shot amplitude compensation to adjust the energy to the same level, and in this way, the contribution of the well shot record and the controllable source record to superposition imaging can be ensured to be completely dependent on the respective coverage times. For example, the energy level may be 2000.
In the specific implementation, the process of extracting the wellgun record and the controllable source record from the seismic data can specifically extract the wellgun record and the controllable source record from the seismic data according to the source type keywords. For example, the source type header of the wellgun is identified as1, i.e., header word 1 is a wellgun record, and the source type header of the vibroseis is identified as 4, i.e., header word 4 is a vibroseis record, which may be obtained from a gun file of the SPS file when the observation system is set up.
In specific implementation, the controllable focus record is subjected to minimum phasing, namely, the controllable focus record is converted from zero phase to minimum phase, and then the controllable focus record after phase conversion is obtained.
In a specific implementation, in order to avoid the influence of noise on matching, in this embodiment, denoising the vibroseis record and the wellgun record after phase conversion is achieved by:
denoising the controlled source record and the well cannon record after phase conversion by adopting a combined denoising mode;
And suppressing mechanical interference on the denoised vibroseis records.
Specifically, the combined denoising mode may be a combination of denoising modes such as suppressing industrial electricity, surface waves, linear noise, abnormal energy, and the like. Because the main noise of the well cannon record is linear noise such as surface wave, the ideal effect can be achieved through the combined denoising mode, the controllable source construction area is generally town, and the mechanical interference is serious, if the noise is suppressed by adopting the same process, the ideal effect cannot be achieved, and therefore, the mechanical interference is suppressed by adopting the combined denoising for the well cannon aiming at the controllable source record, and the parameter is optimized additionally. If noise suppression is carried out on the well cannon by using the group of parameters in a general way, effective signals are inevitably damaged; if the mechanical interference is not suppressed to the controllable vibration source, the quality of the superposition of the wavelet and the profile of the controllable vibration source is difficult to ensure, so that the additional suppression is needed.
In a specific implementation, in order to avoid the influence on matching due to different attenuation degrees of longitudinal energy, in this embodiment, the denoising of the vibroseis record and the denoising of the wellgun record are compensated by the following steps:
Performing longitudinal energy compensation on the controllable seismic source record by adopting a first longitudinal amplitude compensation value;
and adopting a second longitudinal amplitude compensation value to perform longitudinal energy compensation on the well cannon record, wherein the second longitudinal amplitude compensation value is larger than the first longitudinal amplitude compensation value.
Specifically, the energy attenuation degree in the longitudinal direction of the controllable source record is different from that of the well gun record, and the same compensation factor (namely, longitudinal amplitude compensation value) cannot be applied to compensate during amplitude compensation. The attenuation degree of the wellgun record is obviously higher than that of the controllable seismic source record, so that the controllable seismic source record adopts a smaller compensation factor (namely, a first longitudinal amplitude compensation value) in compensation, for example, 1.1 can be selected, and the wellgun record adopts a larger compensation factor (namely, a second longitudinal amplitude compensation value), for example, 1.7 can be selected.
In a specific implementation, in order to avoid the influence on matching due to different phases, in this embodiment, the phase of the vibroseis record after the longitudinal energy compensation is adjusted to be a mixed phase by:
Lifting a controllable focus record wavelet from the controllable focus record subjected to longitudinal energy compensation, and lifting a well cannon record wavelet from the well cannon record subjected to longitudinal energy compensation;
Determining a matching factor according to the cross-correlation between the controllable source record wavelet and the well cannon record wavelet;
and adjusting the phase of the controllable source record subjected to longitudinal energy compensation to be a mixed phase according to the matching factor.
In the implementation, the process of determining the matching factor according to the cross-correlation between the vibroseis recorded wavelet and the wellgun recorded wavelet can be implemented by adopting the prior art, and the application is not particularly limited.
In specific implementation, representative single shots can be preferably selected to extract the vibroseis record wavelet and the wellgun record wavelet respectively, a matching factor is determined based on the cross-correlation of the vibroseis record wavelet and the wellgun record wavelet, and then the process of adjusting the longitudinal energy compensated phase of the vibroseis record into the mixed phase according to the matching factor is essentially a wavelet matching process, and the matching direction is the direction from the vibroseis record wavelet to the wellgun record wavelet. Then the controllable source record applies the matching factor to complete wavelet matching. This is done because the vibroseis record is minimized from the previous minimum phase, whereas the wellgun record is a mixed phase due to the earth absorption attenuation, and the wavelet matching converts the minimum phase vibroseis record to the mixed phase, which is closer to the phase characteristics of the wellgun record.
In a specific implementation, in order to avoid the time difference from affecting the matching, in this embodiment, the time difference between the vibroseis record and the wellgun record in the superimposed data is eliminated by:
Taking two sections of adjacent data near the intersection point of the controllable seismic source record and the well cannon record in the superimposed data, and calculating the cross-correlation value of the two sections of adjacent data;
and carrying out static correction on the controllable seismic source record in the superimposed data according to the time difference corresponding to the cross-correlation maximum value, and eliminating the time difference between the controllable seismic source record and the well cannon record in the superimposed data.
In the specific implementation, two adjacent overlapping sections (the two adjacent overlapping sections are a well gun record overlapping section and a controllable seismic source record overlapping section) are selected from the overlapping data to perform cross-correlation so as to obtain a time difference. When in cross-correlation, the overlapping section of the wellgun records is used as a model channel, the time difference corresponding to the maximum value of the cross-correlation is the time difference between the controllable seismic source record and the wellgun record, and the time difference can be eliminated by applying the time difference to carry out static correction on the controllable seismic source record.
The following describes the process of implementing the above-described method for matching well cannon and vibroseis hybrid acquired seismic data with reference to fig. 2:
step 1: the vibroseis and wellgun recordings are tuned to the same energy level.
Step 2: sorting data according to the key words of the type of the seismic source of the track head, wherein the track head word 4 is a controllable seismic source record, and the track head word 1 is a well cannon record.
Step 3: and (3) performing minimum phasing on the vibroseis records selected in the step (2), and converting the zero phase into the minimum phase.
Step 4: and pressing noise on the controlled source record and the well cannon record after the phase conversion by adopting a conventional combined denoising mode.
Step 5: and (4) suppressing the mechanical interference once again for the vibroseis record after the conventional denoising in the step (4).
Step 6: and (3) respectively selecting proper compensation factors for longitudinal energy compensation for the well gun record after denoising in the step (4) and the controllable source record after denoising in the step (5), wherein the controllable source record adopts smaller compensation factors, such as 1.1, and the well gun record adopts larger compensation factors, such as 1.7.
Step 7: and (5) respectively extracting wavelets of the well gun record and the controllable source record after the amplitude compensation in the step 6.
Step 8: and (3) obtaining a matching factor according to the cross-correlation of the wellgun record wavelet and the controllable source record wavelet, and matching the controllable source record wavelet into the wellgun record wavelet, namely adjusting the phase of the controllable source record after longitudinal energy compensation into a mixed phase according to the matching factor.
Step 9: and (5) respectively superposing the controllable seismic source record and the well cannon record after the wavelet matching in the step 8.
Step 10: and (3) selecting two sections of adjacent data from the superimposed data in the step (9) to perform cross correlation to obtain delay time.
Step 11: and (3) performing static correction on the controllable seismic source record in the superposition data by applying the delay time obtained in the step (10), eliminating time difference, and completing matching.
In this embodiment, a computer device is provided, as shown in fig. 3, including a memory 302, a processor 304, and a computer program stored in the memory and capable of running on the processor, where the processor implements the method for matching seismic data acquired by mixing the wellcannon and the controllable seismic source.
In particular, the computer device may be a computer terminal, a server or similar computing means.
In this embodiment, a computer readable storage medium is provided, which stores a computer program for executing the matching method of seismic data acquired by mixing the wellcannon and the controllable source of any of the above.
In particular, computer-readable storage media, including both permanent and non-permanent, removable and non-removable media, may be used to implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of computer-readable storage media include, but are not limited to, phase-change memory (PRAM), static Random Access Memory (SRAM), dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), read Only Memory (ROM), electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), digital Versatile Disks (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium, which can be used to store information that can be accessed by a computing device. Computer-readable storage media, as defined herein, does not include transitory computer-readable media (transmission media), such as modulated data signals and carrier waves.
Based on the same inventive concept, the embodiment of the invention also provides a device for matching the seismic data acquired by mixing the well cannon and the controllable seismic source, as described in the following embodiment. Because the principle of the matching device for the seismic data acquired by the well cannon and the controllable seismic source in a mixed mode is similar to that of the matching method for the seismic data acquired by the well cannon and the controllable seismic source in a mixed mode, implementation of the matching device for the seismic data acquired by the well cannon and the controllable seismic source in a mixed mode can be seen from implementation of the matching method for the seismic data acquired by the well cannon and the controllable seismic source in a mixed mode, and repeated parts are omitted. As used below, the term "unit" or "module" may be a combination of software and/or hardware that implements the intended function. While the means described in the following embodiments are preferably implemented in software, implementation in hardware, or a combination of software and hardware, is also possible and contemplated.
FIG. 4 is a block diagram of a device for matching seismic data acquired by a combination of a wellgun and a vibroseis in accordance with an embodiment of the present invention, as shown in FIG. 4, the device comprising:
an energy adjustment module 402 for adjusting the vibroseis record and the wellgun record in the seismic data to the same energy level;
The phase conversion module 404 is configured to extract a wellgun record and a vibroseis record from the seismic data, and minimize the vibroseis record to obtain a vibroseis record after phase conversion;
the denoising module 406 is configured to denoise the vibroseis record and the wellgun record after phase conversion;
an energy compensation module 408 for performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record;
a phase adjustment module 410, configured to adjust the phase of the vibroseis record after the longitudinal energy compensation to a hybrid phase;
The data superposition module 412 is configured to superimpose the vibroseis record with the longitudinal energy compensated wellgun record in the mixed phase to obtain superimposed data;
A time difference elimination module 414, configured to eliminate a time difference between the vibroseis record and the wellcannon record in the superimposed data.
In one embodiment, the phase conversion module is specifically configured to extract a wellgun record and a vibroseis record from the seismic data according to a source type key.
In one embodiment, the denoising module is specifically configured to denoise the vibroseis record and the wellgun record after phase conversion by adopting a combined denoising manner; and suppressing mechanical interference on the denoised vibroseis records.
In one embodiment, the energy compensation module is specifically configured to perform longitudinal energy compensation on the vibroseis record using a first longitudinal amplitude compensation value; and adopting a second longitudinal amplitude compensation value to perform longitudinal energy compensation on the well cannon record, wherein the second longitudinal amplitude compensation value is larger than the first longitudinal amplitude compensation value.
In one embodiment, the phase adjustment module is specifically configured to lift a vibroseis record wavelet from the vibroseis record after longitudinal energy compensation, and lift a wellgun record wavelet from the wellgun record after longitudinal energy compensation; determining a matching factor according to the cross-correlation between the controllable source record wavelet and the well cannon record wavelet; and adjusting the phase of the controllable source record subjected to longitudinal energy compensation to be a mixed phase according to the matching factor.
In one embodiment, the time difference eliminating module is specifically configured to take two pieces of adjacent data near an intersection point of the vibroseis record and the wellgun record in the superimposed data, and calculate a cross-correlation value of the two pieces of adjacent data; and carrying out static correction on the controllable seismic source record in the superimposed data according to the time difference corresponding to the cross-correlation maximum value, and eliminating the time difference between the controllable seismic source record and the well cannon record in the superimposed data.
The embodiment of the invention realizes the following technical effects: the method comprises the steps of adjusting a controllable source record and a well gun record in seismic data to the same energy level, taking the influence of the energy level on matching into consideration, extracting the well gun record and the controllable source record from the seismic data, carrying out minimum phasing on the controllable source record to obtain the controllable source record after phase conversion, carrying out denoising on the controllable source record and the well gun record after phase conversion, and taking the influence of noise on matching into consideration; performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record, namely considering the influence of the longitudinal attenuation degree on matching, and adjusting the phase of the vibroseis record after the longitudinal energy compensation to be a mixed phase, so that the unmixed phases of the vibroseis record and the wellgun record are realized, and considering the influence of the phase on matching; further, overlapping the controllable seismic source record with the mixed phase and the well cannon record subjected to longitudinal energy compensation to obtain overlapped data; and finally, eliminating the time difference between the controllable seismic source record and the well cannon record in the superimposed data, taking the influence of the time difference on matching into consideration, realizing a matching method which is more comprehensive in consideration and has stronger adaptability to well-seismic combined acquisition data with low signal-to-noise ratio, and being beneficial to laying a foundation for improving the imaging quality of the data.
It will be apparent to those skilled in the art that the modules or steps of the embodiments of the invention described above may be implemented in a general purpose computing device, they may be concentrated on a single computing device, or distributed across a network of computing devices, they may alternatively be implemented in program code executable by computing devices, so that they may be stored in a storage device for execution by computing devices, and in some cases, the steps shown or described may be performed in a different order than what is shown or described, or they may be separately fabricated into individual integrated circuit modules, or a plurality of modules or steps in them may be fabricated into a single integrated circuit module. Thus, embodiments of the invention are not limited to any specific combination of hardware and software.
The above description is only of the preferred embodiments of the present invention and is not intended to limit the present invention, and various modifications and variations can be made to the embodiments of the present invention by those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (8)
1. A method for matching seismic data acquired by mixing a well cannon and a controllable seismic source is characterized by comprising the following steps:
adjusting the controllable source record and the well cannon record in the seismic data to the same energy level;
Extracting a wellgun record and a controllable source record from the seismic data, and performing minimum phasing on the controllable source record to obtain the controllable source record after phase conversion;
Denoising the controlled source record and the well cannon record after phase conversion;
performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record;
adjusting the phase of the controllable seismic source record after longitudinal energy compensation to be a mixed phase;
superposing the controllable seismic source record with the mixed phase and the well cannon record subjected to longitudinal energy compensation to obtain superposition data;
eliminating time difference between the controllable source record and the well cannon record in the superposition data;
The method for performing longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record comprises the following steps:
Performing longitudinal energy compensation on the controllable seismic source record by adopting a first longitudinal amplitude compensation value;
and adopting a second longitudinal amplitude compensation value to perform longitudinal energy compensation on the well cannon record, wherein the second longitudinal amplitude compensation value is larger than the first longitudinal amplitude compensation value.
2. The method of matching well cannon and vibroseis hybrid acquired seismic data of claim 1, wherein extracting well cannon records and vibroseis records from the seismic data comprises:
And extracting the wellgun records and the controllable source records from the seismic data according to the source type keywords.
3. The method for matching seismic data acquired by mixing a wellgun and a vibroseis of claim 1, wherein denoising the vibroseis record and the wellgun record after phase conversion comprises:
denoising the controlled source record and the well cannon record after phase conversion by adopting a combined denoising mode;
And suppressing mechanical interference on the denoised vibroseis records.
4. The method of matching well cannon and vibroseis hybrid acquired seismic data of claim 1, wherein adjusting the phase of the vibroseis record after longitudinal energy compensation to a hybrid phase comprises:
extracting a controllable focus record wavelet from the controllable focus record subjected to longitudinal energy compensation, and extracting a wellgun record wavelet from the wellgun record subjected to longitudinal energy compensation;
Determining a matching factor according to the cross-correlation between the controllable source record wavelet and the well cannon record wavelet;
and adjusting the phase of the controllable source record subjected to longitudinal energy compensation to be a mixed phase according to the matching factor.
5. The method of matching well cannon and vibroseis hybrid acquired seismic data of any of claims 1-4, wherein eliminating the time difference between the vibroseis record and the well cannon record in the superimposed data comprises:
Taking two sections of adjacent data near the intersection point of the controllable seismic source record and the well cannon record in the superimposed data, and calculating the cross-correlation value of the two sections of adjacent data;
and carrying out static correction on the controllable seismic source record in the superimposed data according to the time difference corresponding to the cross-correlation maximum value, and eliminating the time difference between the controllable seismic source record and the well cannon record in the superimposed data.
6. A device for matching seismic data acquired by a combination of a borehole and a vibroseis, comprising:
The energy adjustment module is used for adjusting the controllable source record and the well cannon record in the seismic data to the same energy level;
The phase conversion module is used for extracting a wellgun record and a controllable source record from the seismic data, and performing minimum phase minimization on the controllable source record to obtain the controllable source record after phase conversion;
The denoising module is used for denoising the controlled source record and the well cannon record after the phase conversion;
The energy compensation module is used for carrying out longitudinal energy compensation on the denoised vibroseis record and the denoised wellgun record;
the phase adjustment module is used for adjusting the phase of the controllable seismic source record after longitudinal energy compensation to be a mixed phase;
the data superposition module is used for superposing the controllable seismic source record of the mixed phase and the well cannon record after longitudinal energy compensation to obtain superposition data;
The time difference eliminating module is used for eliminating the time difference between the controllable source record and the well cannon record in the superposition data;
The energy compensation module is specifically used for carrying out longitudinal energy compensation on the controllable seismic source record by adopting a first longitudinal amplitude compensation value; and adopting a second longitudinal amplitude compensation value to perform longitudinal energy compensation on the well cannon record, wherein the second longitudinal amplitude compensation value is larger than the first longitudinal amplitude compensation value.
7. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein execution of the computer program by the processor implements a method of matching seismic data acquired by a well cannon and a vibroseis hybrid as claimed in any one of claims 1 to 5.
8. A computer readable storage medium, characterized in that it stores a computer program, which when executed by a processor, implements a method for matching seismic data acquired by mixing a wellcannon and a vibroseis according to any one of claims 1 to 5.
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