Joint imaging method and device for DAS-VSP data and ground seismic data

Abstract

The invention discloses a joint imaging method and device for DAS-VSP data and ground seismic data, and the method comprises the steps: collecting the ground seismic data, and collecting the DAS-VSP data; performing wave field separation on the DAS-VSP data of the left well and the right well to obtain first seismic wave field information; obtaining second seismic wave field information by adopting a Marchenko iterative algorithm and the ground seismic data; screening same seismic source data from the ground seismic data, the first seismic wave field information and the second seismic wave field information; and performing normalization adjustment on the same-source data to obtain same-source three-dimensional exploration seismic data, performing Kirchhoff prestack migration processing on the same-source three-dimensional exploration seismic data, outputting a migration result, and respectively processing the DAS-VSP data and the ground seismic data to obtain a detection point which is located in the ground surface and the wells on the two sides, and a detection point which is located in the ground surface and the wells on the two sides. Omnibearing three-dimensional exploration data on an underground virtual calibration surface is used for prestack depth migration, and exploration imaging precision is improved.

Description

Technical Field

[0001] This application relates to the field of geographic exploration technology, and more specifically, to a method and apparatus for joint imaging of DAS-VSP data and ground seismic data. Background Technology

[0002] With the development of technology, DAS (Distributed Acoustic Sensing) technology, with its advantages of low cost and high-density sampling, has gradually emerged in the field of seismic observation, providing new data acquisition methods for oil and gas exploration. DAS technology utilizes optical fibers as sensors, enabling long-distance, high-density seismic data acquisition, effectively improving the efficiency and coverage of seismic data acquisition, while also reducing the cost and difficulty of deploying traditional geophones. However, existing well-seismic co-location methods mainly focus on velocity modeling and geological interpretation, often relying on well-seismic error velocity modeling. By comparing and analyzing well seismic data with surface seismic data, the seismic velocity model is corrected and optimized to improve the accuracy of geological interpretation. However, there is currently no joint inversion technology for well-seismic co-locations but different geophone points, which to some extent limits the full utilization of seismic data and more accurate imaging of subsurface geological structures.

[0003] Chinese patent application CN104090299A discloses a method for amplitude compensation of ground seismic data based on the first arrival wave of a VSP (Vertical Seismic Profile). The method includes: S1 first separating the downflow wave from the VSP data, then automatically picking the first arrival time of each VSP data trace from the downflow wave, and obtaining the amplitude corresponding to the first arrival time of each VSP data trace, forming a data sequence; S2 fitting the data sequence with an exponential curve, and using a nonlinear inversion method to calculate the exponent x of the exponential curve; S3 multiplying the amplitude of each sample point in the ground seismic data trace by the x-th power of the corresponding time value of each sample point to perform time function gain on the ground seismic data and achieve amplitude compensation.

[0004] This invention can effectively compensate for the deep energy in surface seismic data, achieving true amplitude recovery of seismic data and helping to improve the prediction accuracy of oil and gas reservoirs. It differs significantly from this invention and cannot solve the technical problem that this invention aims to address.

[0005] Chinese patent application CN115826043A discloses a method for reconstructing VSP data into ground seismic data. The method includes: S1 extracting the direct wave field from the VSP shot gather record; S2 transforming the direct wave field di, which serves as the shot gather at the i-th virtual source point, into the τ-p domain using Radon transform; S3 extracting the positive ray parameter from ud; S4 transforming the residual wave field gi, which serves as the shot gather at the i-th virtual source point, into the τ-p domain using Radon transform; S5 extracting the positive ray parameter from ug; and S6 transforming the direct wave field dj, which serves as the shot gather at the j-th ground reference receiver point, into the τ-p domain using Radon transform. S7 Extract the positive values ​​of the ray parameters from ud; S8 Transform the residual wave field gj of the shot gather at the j-th ground reference receiver point to the τ-p domain using Radon transform; S9 Extract the positive values ​​of the ray parameters from ug; S10 Perform cross-correlation and superposition operations on ud and ug; S11 Perform convolution and superposition operations on ud and ug; S12 Repeat steps 6 to 11 for all reference receiver points j; S13 Repeat steps 2 to 12 for all virtual sources i to obtain all reconstructed ground seismic data.

[0006] This invention, through further joint data processing of the original VSP data and reconstructed ground seismic data, can improve the imaging accuracy of underground geological structures and effectively expand the imaging range of underground geological structures, thereby obtaining high-quality imaging results. This is significantly different from the present invention and cannot solve the technical problem that the present invention aims to address.

[0007] Chinese patent application CN117997308A discloses a method, apparatus, device, and storage medium for VSP corridor filtering with ground seismic constraints. The method includes: S1 using VSP corridor stacked profile P-wave data and ground seismic data from the target well as first data and second data respectively, and dividing the first data and second data into time windows according to a preset time window size; S2 determining a filtering factor based on the first data and second data within the time window; S3 adjusting the preset time window size, and re-performing the step of dividing the first data and second data into time windows according to the adjusted time window size to obtain multiple sets of filtering factors; S4 calculating a cross-correlation coefficient between the filtered corridor obtained by filtering the first data based on each set of filtering factors and the second data, and using the filtering factor corresponding to the largest cross-correlation coefficient to filter the first data, thereby obtaining the most suitable filtering factor for VSP corridor filtering.

[0008] This invention ensures a high degree of agreement between corridor filtering and ground seismic data, and accurate layer calibration. It differs significantly from this invention and cannot solve the technical problem this invention aims to address. Summary of the Invention

[0009] This invention provides a method and apparatus for joint imaging of DAS-VSP data and ground seismic data, to solve the technical problems of the prior art as described in the background section. The method includes: Collect ground seismic data and DAS-VSP data; Wavefield separation was performed on the DAS-VSP data from the left and right wells to obtain the wavefield information of the first seismic wave; The Marchenko iterative algorithm and ground seismic data were used to obtain the wavefield information of the second seismic wave. The source of the second seismic wave was located on the ground surface and the receiver was located on the underground virtual calibration surface. Co-source data are selected from the ground seismic data, the first seismic wave wavefield information, and the second seismic wave wavefield information; The co-source data is normalized and adjusted to obtain co-source stereo exploration seismic data. The co-source stereo exploration seismic data is then subjected to Kirchhoff pre-stack migration processing, and the migration results are output.

[0010] In some specific embodiments, DAS-VSP data is collected, specifically as follows: The seismic source point is set at the ground surface, and a distributed optical fiber sensor is placed inside the well to acquire the DAS-VSP data.

[0011] In some specific embodiments, before performing wavefield separation on DAS-VSP data from different well locations, the following steps are also included: The DAS-VSP data is subjected to static correction, first arrival picking, spherical diffusion compensation, amplitude consistency processing and wavelet consistency processing in sequence to obtain DAS-VSP data for different well locations.

[0012] In some specific embodiments, wavefield separation is performed on the DAS-VSP data of the left and right wells to obtain the first seismic wave field information, specifically as follows: Wavefield separation was performed on the DAS-VSP data of the left and right wells respectively to extract the left traveling wave and the right traveling wave; The left-traveling wave and the right-traveling wave are used as the wavefield information of the first seismic wave.

[0013] In some specific embodiments, before obtaining the second seismic wavefield information using the Marchenko iterative algorithm and ground seismic data, the following steps are also included: A virtual underground calibration surface is determined in advance based on exploration needs, and a virtual seismic source is placed on the virtual underground calibration surface.

[0014] In some specific embodiments, the Marchenko iterative algorithm and ground seismic data are used to obtain the second seismic wavefield information, specifically: The ground seismic data is denoised to obtain preprocessed ground seismic data. Obtain the direct wave response from the underground virtual point to the surface; The preprocessed ground seismic data and the direct wave response are used as inputs. The downlink Green's function is obtained based on the Marchenko iterative algorithm, and the downlink Green's function is used as the second seismic wave field information.

[0015] In some specific embodiments, the coseismic source data is normalized and adjusted, specifically as follows: Deconvolution operators are extracted from DAS-VSP data at different well locations, and the surface seismic data is deconvolved based on the deconvolution operators to make the wavelet morphology of the DAS-VSP data at different well locations more consistent with that of the surface seismic data.

[0016] Accordingly, the present invention also proposes a joint imaging device for DAS-VSP data and ground seismic data, the device comprising: The acquisition module is used to acquire ground seismic data and DAS-VSP data; The wavefield separation module is used to separate the wavefields of the DAS-VSP data from the left and right wells to obtain the first seismic wavefield information. The acquisition module is used to acquire the second seismic wave field information using the Marchenko iterative algorithm and ground seismic data. The source of the second seismic wave field information is located on the ground surface and the receiver is located on the underground virtual calibration surface. The filtering module is used to filter out co-source data from the ground seismic data, the first seismic wave wavefield information and the second seismic wave wavefield information; The output module is used to normalize and adjust the coseismic data to obtain coseismic stereo exploration seismic data, perform Kirchhoff pre-stack migration processing on the coseismic stereo exploration seismic data, and output the migration results.

[0017] One embodiment of the present invention also provides a computing device, including: a memory and a processor; the memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions, which, when executed by the processor, implement the steps of the joint imaging method of DAS-VSP data and ground seismic data as described in any of the above.

[0018] One embodiment of the present invention also provides a computer-readable storage medium storing computer-executable instructions that, when executed by a processor, implement the steps of the joint imaging method of DAS-VSP data and ground seismic data as described in any of the above claims.

[0019] By applying the above technical solutions, a joint imaging method for DAS-VSP data and ground seismic data is proposed. The method includes: acquiring ground seismic data and DAS-VSP data; performing wavefield separation on the DAS-VSP data from the left and right wells to obtain the first seismic wave field information; using the Marchenko iterative algorithm and ground seismic data to obtain the second seismic wave field information, wherein the source of the second seismic wave field information is located on the surface and the receiver is located on the underground virtual calibration surface; filtering out co-source data from the ground seismic data, the first seismic wave field information, and the second seismic wave field information; normalizing and adjusting the co-source data to obtain co-source stereo exploration seismic data, and performing Kirchhoff pre-stack migration processing on the co-source stereo exploration seismic data, and outputting the migration results. After processing the DAS-VSP data and ground seismic data respectively, all-round stereo exploration data with receivers located on the surface, in both wells, and on the underground virtual calibration surface can be obtained. Using this data for pre-stack depth migration improves the accuracy of exploration imaging. Attached Figure Description

[0020] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0021] Figure 1 This is a flowchart illustrating a method for joint imaging of DAS-VSP data and ground seismic data provided in an embodiment of this application; Figure 2 This is a schematic diagram of the DAS-VSP observation system provided in the embodiments of this application; Figure 3 This is a schematic diagram of the DAS-VSP observation system after wavefield separation provided in the embodiments of this application; Figure 4 This is a schematic diagram of the combined imaging observation system of DAS-VSP and ground seismic data provided in the embodiments of this application; Figure 5 This is a schematic diagram of the classic wedge model provided in the embodiments of this application; Figure 6 This is a schematic diagram of the ground seismic imaging results provided in an embodiment of this application; Figure 7 This is a schematic diagram of the combined imaging results provided in an embodiment of this application; Figure 8This is a schematic diagram of the structure of a combined imaging device for DAS-VSP data and ground seismic data provided in an embodiment of this application; Figure 9 This is a structural block diagram of a computing device provided in an embodiment of this application. Detailed Implementation

[0022] Many specific details are set forth in the following description to provide a full understanding of this specification. However, this specification can be implemented in many other ways than those described herein, and those skilled in the art can make similar extensions without departing from the spirit of this specification. Therefore, this specification is not limited to the specific implementations disclosed below.

[0023] The terminology used in one or more embodiments of this specification is for the purpose of describing particular embodiments only and is not intended to be limiting of the one or more embodiments of this specification. The singular forms “a” and “the” as used in one or more embodiments of this specification and the appended claims are also intended to include the plural forms, unless the context clearly indicates otherwise. It should also be understood that the term “and / or” as used in one or more embodiments of this specification refers to and includes any or all possible combinations of one or more associated listed items.

[0024] It should be understood that although the terms first, second, etc., may be used to describe various information in one or more embodiments of this specification, such information should not be limited to these terms. These terms are only used to distinguish information of the same type from one another. For example, first may also be referred to as second without departing from the scope of one or more embodiments of this specification, and similarly, second may also be referred to as first. Depending on the context, the word "if" as used herein may be interpreted as "when," "when," or "in response to a determination."

[0025] This patent addresses the issue that DAS-VSP data and ground seismic data cannot be used for joint migration of co-source data. It applies wavefield separation and the Marchenko iterative algorithm to both DAS-VSP and ground seismic data respectively, thereby constructing co-source 3D exploration data and performing amplitude and phase normalization adjustments. Using this data as migration input yields a comprehensive exploration imaging map.

[0026] Specifically, such as Figures 1-7 As shown, this application proposes a joint imaging method using DAS-VSP data and ground seismic data, the method comprising the following steps: Step S101: Collect ground seismic data and DAS-VSP data.

[0027] In one possible implementation, DAS-VSP data is collected, specifically as follows: The seismic source point is set at the ground surface, and a distributed optical fiber sensor is placed inside the well to acquire the DAS-VSP data.

[0028] Specifically, both the source and receiver are located on the Earth's surface, and 3D seismic data is collected, covering the target area. Forward modeling in the model yields the "surface reflection response." At this point, a virtual calibration surface can be selected underground according to exploration and development needs. A virtual source is placed at the virtual calibration surface, and forward modeling yields the "subsurface direct wave response." This step allows us to obtain seismic waves with the source and receiver located on the Earth's surface.

[0029] Specifically, with the epicenter located at the Earth's surface, distributed fiber optic sensors are placed in wells to acquire DAS-VSP data. DAS technology utilizes optical fibers as sensors, offering advantages such as high-density sampling and low cost. This step yields the full wavefield of seismic waves with the epicenter at the surface and the receivers located in wells on either side.

[0030] Specifically, such as Figure 2 As shown, the DAS-VSP observation system is illustrated. Sources and receivers are positioned on the surface, while receivers are positioned inside the DAS-VSP well. However, the wavefield is complex, with non-uniform waveforms, including both left- and right-traveling waves. There are no receivers underground at this point.

[0031] Step S102: Perform wavefield separation on the DAS-VSP data of the left and right wells to obtain the wavefield information of the first seismic wave.

[0032] In one possible implementation, before performing wavefield separation on DAS-VSP data from different well locations, the following steps are also included: The DAS-VSP data is subjected to static correction, first arrival picking, spherical diffusion compensation, amplitude consistency processing and wavelet consistency processing in sequence to obtain DAS-VSP data for different well locations.

[0033] In one possible implementation, wavefield separation is performed on the DAS-VSP data from the left and right wells to obtain the first seismic wave field information, specifically as follows: Wavefield separation was performed on the DAS-VSP data of the left and right wells respectively to extract the left traveling wave and the right traveling wave; The left-traveling wave and the right-traveling wave are used as the wavefield information of the first seismic wave.

[0034] In this embodiment, a triple constraint mechanism involving the time domain, frequency domain, and phase domain is used to ensure that the reconstructed wavelet maintains a high degree of consistency with the seismic response characteristics of the target stratum.

[0035] like Figure 3As shown, the DAS-VSP observation system after wavefield separation is demonstrated. The singular value decomposition technique can obtain the wavefield of a single component, for example, the left well contains only left traveling waves and the right well contains only right traveling waves. This step realizes the processing of DAS-VSP data.

[0036] In this embodiment, the DAS-VSP data undergoes static correction, first arrival pickup, spherical spread compensation, amplitude consistency processing, and wavelet consistency processing. These processing steps improve data quality and provide a better data foundation for subsequent imaging.

[0037] In this embodiment, wavefield separation is performed on DAS-VSP data from different well locations to extract left-traveling and right-traveling waves. This step yields the wavefield information of seismic waves with the source located at the surface and the receivers located in the two wells on either side.

[0038] Step S103: The Marchenko iterative algorithm and ground seismic data are used to obtain the second seismic wave field information. The source of the second seismic wave field information is located on the ground surface and the receiver is located on the underground virtual calibration surface.

[0039] In one possible implementation, before using the Marchenko iterative algorithm and ground seismic data to obtain the second seismic wavefield information, the following steps are also included: A virtual underground calibration surface is determined in advance based on exploration needs, and a virtual seismic source is placed on the virtual underground calibration surface.

[0040] In one possible implementation, the Marchenko iterative algorithm and ground seismic data are used to obtain the second seismic wavefield information, specifically as follows: The ground seismic data is denoised to obtain preprocessed ground seismic data. Obtain the direct wave response from the underground virtual point to the surface; The preprocessed ground seismic data and the direct wave response are used as inputs. The downlink Green's function is obtained based on the Marchenko iterative algorithm, and the downlink Green's function is used as the second seismic wave field information.

[0041] In this embodiment, ground seismic data preprocessing (denoising, surface correlation multiple removal, and source wavelet deconvolution) is used to calculate the direct wave response Gd from the subsurface virtual point to the surface. The preprocessed ground seismic shot record and Gd are used as input. The descending Green's function G+ is calculated using Marchenko iteration. This step yields the seismic wavefield information for a source located at the surface and a receiver located at the subsurface virtual calibration surface.

[0042] like Figure 4As shown, the observation system of the underground virtual calibration surface for ground seismic data is demonstrated. According to the actual work requirements, the underground virtual calibration surface is set up, and the reflection response and direct wave response are obtained by performing two forward models. According to the iterative Marchenko algorithm, the downlink Green's function of the surface excitation and the underground virtual calibration surface reception can be obtained. At this time, it is equivalent to setting up a receiver point underground.

[0043] Step S104: Select co-source data from the ground seismic data, the first seismic wave field information and the second seismic wave field information.

[0044] In this embodiment, step S101 obtains the ascending wave field of the geophone point located at the surface. Step S102 obtains the left-hand traveling wave field of the geophone point located in the left well and the right-hand traveling wave field of the geophone point located in the right well. Step S103 obtains the descending wave field of the geophone point located on the underground virtual calibration surface. Thus, 360-degree three-dimensional seismic wave exploration information surrounding the target area by the geophone point can be obtained.

[0045] like Figure 5 As shown, this demonstrates a joint imaging observation system of DAS-VSP and ground seismic data; it integrates the Green's function of surface receivers and... Figure 3 and Figure 4 Green's functions are selected from seismic sources with the same source, and Kirchhoff pre-stack depth migration is performed on the seismic data. This enables comprehensive three-dimensional seismic exploration.

[0046] Step S105: Normalize and adjust the co-source data to obtain co-source stereo exploration seismic data, perform Kirchhoff pre-stack migration processing on the co-source stereo exploration seismic data, and output the migration results.

[0047] In one possible implementation, the co-source data is normalized and adjusted, specifically as follows: Deconvolution operators are extracted from DAS-VSP data at different well locations, and the surface seismic data is deconvolved based on the deconvolution operators to make the wavelet morphology of the DAS-VSP data at different well locations more consistent with that of the surface seismic data.

[0048] In this embodiment, the deconvolution operator is extracted from DAS-VSP data and deconvolved on the ground seismic data, which can suppress multiple waves and make the wavelet morphology of the two types of seismic data more consistent.

[0049] In this embodiment, the obtained co-source stereoscopic exploration seismic data is used to perform Kirchhoff pre-stack migration processing to obtain the migration result located between the two wells, above the subsurface virtual calibration surface.

[0050] like Figure 6 The image shows the results of ground seismic imaging. From Figure 6As can be seen, some structures are poorly imaged and require local enhancement processing.

[0051] Figure 7 The combined imaging results are presented. From Figure 7 As can be seen, the fault structure was effectively imaged, the phase axes are more continuous, the vertical resolution is improved, and the minute undulations of the strata are clearly reproduced. In summary, this invention proposes a joint imaging method using DAS-VSP data and surface seismic data. The method includes: acquiring surface seismic data and DAS-VSP data; performing wavefield separation on the DAS-VSP data from the left and right wells to obtain first seismic wavefield information; using the Marchenko iterative algorithm and surface seismic data to obtain second seismic wavefield information, wherein the source of the second seismic wavefield information is located at the surface and the receiver is located on a subsurface virtual calibration surface; filtering co-source data from the surface seismic data, the first seismic wavefield information, and the second seismic wavefield information; normalizing and adjusting the co-source data to obtain co-source stereoscopic exploration seismic data; performing Kirchhoff pre-stack migration processing on the co-source stereoscopic exploration seismic data and outputting the migration results. After processing the DAS-VSP data and surface seismic data respectively, omnidirectional stereoscopic exploration data with receivers located at the surface, in both wells, and on the subsurface virtual calibration surface can be obtained. Using this data for pre-stack depth migration improves the accuracy of exploration imaging.

[0052] This application also proposes a joint imaging device for DAS-VSP data and ground seismic data, such as... Figure 8 As shown, the device includes: The acquisition module is used to acquire ground seismic data and DAS-VSP data; The wavefield separation module is used to separate the wavefields of the DAS-VSP data from the left and right wells to obtain the first seismic wavefield information. The acquisition module is used to acquire the second seismic wave field information using the Marchenko iterative algorithm and ground seismic data. The source of the second seismic wave field information is located on the ground surface and the receiver is located on the underground virtual calibration surface. The filtering module is used to filter out co-source data from the ground seismic data, the first seismic wave wavefield information and the second seismic wave wavefield information; The output module is used to normalize and adjust the coseismic data to obtain coseismic stereo exploration seismic data, perform Kirchhoff pre-stack migration processing on the coseismic stereo exploration seismic data, and output the migration results.

[0053] Figure 9A structural block diagram of a computing device 400 according to one embodiment of this specification is shown. The components of the computing device 400 include, but are not limited to, a memory 410 and a processor 420. The processor 420 is connected to the memory 410 via a bus 430, and a database 450 is used to store data.

[0054] The computing device 400 also includes an access device 440, which enables the computing device 400 to communicate via one or more networks 460. Examples of these networks include Public Switched Telephone Network (PSTN), Local Area Network (LAN), Wide Area Network (WAN), Personal Area Network (PAN), or combinations of communication networks such as the Internet. The access device 440 may include one or more of any type of wired or wireless network interface (e.g., a network interface card (NIC)), such as an IEEE 802.11 Wireless Local Area Network (WLAN) wireless interface, a Wi-MAX (Worldwide Interoperability for Microwave Access) interface, an Ethernet interface, a Universal Serial Bus (USB) interface, a cellular network interface, a Bluetooth interface, or a Near Field Communication (NFC) interface.

[0055] In one embodiment of this specification, the aforementioned components of the computing device 400 and Figure 9 Other components, not shown, can also be connected to each other, for example, via a bus. It should be understood that... Figure 9 The block diagram of the computing device shown is for illustrative purposes only and is not intended to limit the scope of this specification. Those skilled in the art can add or replace other components as needed.

[0056] The computing device 400 can be any type of stationary or mobile computing device, including mobile computers or mobile computing devices (e.g., tablet computers, personal digital assistants, laptop computers, notebook computers, netbooks, etc.), mobile phones (e.g., smartphones), wearable computing devices (e.g., smartwatches, smart glasses, etc.) or other types of mobile devices, or stationary computing devices such as desktop computers or personal computers (PCs). The computing device 400 can also be a mobile or stationary server.

[0057] The processor 420 executes computer-executable instructions, which, when executed by the processor, implement the steps of the aforementioned joint imaging method of DAS-VSP data and ground seismic data. The above is an illustrative scheme of a computing device according to this embodiment. It should be noted that the technical solution of this computing device and the technical solution of the aforementioned joint imaging method of DAS-VSP data and ground seismic data belong to the same concept. Details not described in detail in the technical solution of the computing device can be found in the description of the technical solution of the aforementioned joint imaging method of DAS-VSP data and ground seismic data.

[0058] An embodiment of this specification also provides a computer-readable storage medium storing computer-executable instructions that, when executed by a processor, implement the steps of the above-described method for joint imaging of DAS-VSP data and ground seismic data.

[0059] The above is an illustrative scheme of a computer-readable storage medium according to this embodiment. It should be noted that the technical solution of this storage medium belongs to the same concept as the technical solution of the above-described joint imaging method of DAS-VSP data and ground seismic data. For details not described in detail in the technical solution of the storage medium, please refer to the description of the technical solution of the above-described joint imaging method of DAS-VSP data and ground seismic data.

[0060] An embodiment of this specification also provides a computer program, wherein when the computer program is executed in a computer, it causes the computer to perform the steps of the above-described method for joint imaging of DAS-VSP data and ground seismic data.

[0061] The above is an illustrative scheme of a computer program according to this embodiment. It should be noted that the technical solution of this computer program belongs to the same concept as the technical solution of the above-described joint imaging method of DAS-VSP data and ground seismic data. For details not described in detail in the technical solution of the computer program, please refer to the description of the technical solution of the above-described joint imaging method of DAS-VSP data and ground seismic data.

[0062] The foregoing has described specific embodiments of this specification. Other embodiments are within the scope of the appended claims. In some cases, the actions or steps recited in the claims may be performed in a different order than that shown in the embodiments and may still achieve the desired result. Furthermore, the processes depicted in the drawings do not necessarily require the specific or sequential order shown to achieve the desired result. In some embodiments, multitasking and parallel processing are possible or may be advantageous.

[0063] The computer instructions include computer program code, which may be in the form of source code, object code, executable file, or some intermediate form. The computer-readable medium may include: any entity or device capable of carrying the computer program code, recording media, USB flash drive, portable hard drive, magnetic disk, optical disk, computer memory, read-only memory (ROM), random access memory (RAM), electrical carrier signals, telecommunication signals, and software distribution media, etc. It should be noted that the content included in the computer-readable medium may be appropriately added to or subtracted according to the requirements of legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable media may not include electrical carrier signals and telecommunication signals.

[0064] It should be noted that, for the sake of simplicity, the foregoing method embodiments are all described as a series of actions. However, those skilled in the art should understand that the embodiments in this specification are not limited to the described order of actions, because according to the embodiments in this specification, some steps can be performed in other orders or simultaneously. Furthermore, those skilled in the art should also understand that the embodiments described in this specification are all preferred embodiments, and the actions and modules involved are not necessarily essential to the embodiments in this specification.

[0065] In the above embodiments, the descriptions of each embodiment have different focuses. For parts not described in detail in a certain embodiment, please refer to the relevant descriptions of other embodiments.

[0066] The preferred embodiments disclosed above are merely illustrative of this specification. The optional embodiments do not exhaustively describe all details, nor do they limit the invention to the specific implementations described. Clearly, many modifications and variations can be made based on the embodiments described herein. These embodiments are selected and specifically described in this specification to better explain the principles and practical applications of the embodiments, thereby enabling those skilled in the art to better understand and utilize this specification. This specification is limited only by the claims and their full scope and equivalents.

Claims

1. A method for joint imaging of DAS-VSP data and ground seismic data, characterized in that, The method includes: Collect ground seismic data and DAS-VSP data; Wavefield separation was performed on the DAS-VSP data from the left and right wells to obtain the wavefield information of the first seismic wave; The Marchenko iterative algorithm and ground seismic data were used to obtain the second seismic wave field information. The source of the second seismic wave field information was located on the ground surface and the receiver was located on the underground virtual calibration surface. Co-source data are selected from the ground seismic data, the first seismic wave wavefield information, and the second seismic wave wavefield information; The co-source data is normalized and adjusted to obtain co-source stereo exploration seismic data. The co-source stereo exploration seismic data is then subjected to Kirchhoff pre-stack migration processing, and the migration results are output.

2. The method according to claim 1, characterized in that, The data collected from DAS-VSP is as follows: The seismic source point is set at the ground surface, and a distributed optical fiber sensor is placed inside the well to acquire the DAS-VSP data.

3. The method according to claim 1, characterized in that, Before performing wavefield separation on DAS-VSP data from different well locations, the following steps are also included: The DAS-VSP data is subjected to static correction, first arrival picking, spherical diffusion compensation, amplitude consistency processing and wavelet consistency processing in sequence to obtain DAS-VSP data for different well locations.

4. The method according to claim 3, characterized in that, Wavefield separation was performed on the DAS-VSP data from the left and right wells to obtain the first seismic wave field information, specifically: Wavefield separation was performed on the DAS-VSP data of the left and right wells respectively to extract the left traveling wave and the right traveling wave; The left-traveling wave and the right-traveling wave are used as the wavefield information of the first seismic wave.

5. The method according to claim 1, characterized in that, Before using the Marchenko iterative algorithm and ground seismic data to obtain the second seismic wavefield information, the following steps are also included: A virtual underground calibration surface is determined in advance based on exploration needs, and a virtual seismic source is placed on the virtual underground calibration surface.

6. The method according to claim 5, characterized in that, The second seismic wavefield information was obtained using the Marchenko iterative algorithm and surface seismic data, specifically as follows: The ground seismic data is denoised to obtain preprocessed ground seismic data. Obtain the direct wave response from the underground virtual point to the surface; The preprocessed ground seismic data and the direct wave response are used as inputs. The downlink Green's function is obtained based on the Marchenko iterative algorithm, and the downlink Green's function is used as the second seismic wave field information.

7. The method according to claim 1, characterized in that, The co-source data is normalized and adjusted as follows: Deconvolution operators are extracted from DAS-VSP data at different well locations, and the surface seismic data is deconvolved based on the deconvolution operators to make the wavelet morphology of the DAS-VSP data at different well locations more consistent with that of the surface seismic data.

8. A combined imaging device for DAS-VSP data and ground seismic data, characterized in that, The device includes: The acquisition module is used to acquire ground seismic data and DAS-VSP data; The wavefield separation module is used to separate the wavefields of the DAS-VSP data from the left and right wells to obtain the wavefield information of the first seismic wave. The acquisition module is used to acquire the second seismic wave field information using the Marchenko iterative algorithm and ground seismic data. The source of the second seismic wave field information is located on the ground surface and the receiver is located on the underground virtual calibration surface. The filtering module is used to filter out co-source data from the ground seismic data, the first seismic wave wavefield information and the second seismic wave wavefield information; The output module is used to normalize and adjust the coseismic data to obtain coseismic stereo exploration seismic data, perform Kirchhoff pre-stack migration processing on the coseismic stereo exploration seismic data, and output the migration results.

9. A computing device, characterized in that, include: Memory and processor; The memory is used to store computer-executable instructions, and the processor is used to execute the computer-executable instructions. When the computer-executable instructions are executed by the processor, they implement the steps of the joint imaging method of DAS-VSP data and ground seismic data as described in any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, It stores computer-executable instructions that, when executed by a processor, implement the steps of the joint imaging method of DAS-VSP data and ground seismic data as described in any one of claims 1 to 7.

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