A method, device, equipment and readable medium for identifying internal interbed multiple

Abstract

The application discloses a method for identifying internal interlayer multiple waves, which comprises the following steps: searching for a point of uplink wave horizontal homodromous axis interruption as a first-order uplink interruption point, searching for a point of downlink wave interruption in a direction of time decrease along a downlink wave where the first-order uplink interruption point is located as a first-order downlink interruption point, and setting the first-order uplink interruption point as a reference point; searching for a point of downlink wave interruption in a direction of depth decrease along an uplink wave where the reference point is located as a current-order downlink interruption point, searching for a point of uplink wave interruption in a direction of time increase along a downlink wave where the current-order downlink interruption point is located as a current-order uplink interruption point, and setting the current-order uplink interruption point as the reference point; repeating the above step to obtain all current-order uplink interruption points and all current-order downlink interruption points, to obtain time where first-order / current-order interlayer multiple waves are located and time where a lower interface generating the first-order / current-order interlayer multiple waves is located, and to obtain time where an upper interface generating the first-order / current-order interlayer multiple waves is located.

Description

TECHNICAL FIELD

[0001] The present application relates to the field of oil exploration technology, and particularly relates to a method and device for identifying internal interlayer multiple waves, equipment and readable medium. BACKGROUND

[0002] In the Junggar Basin, coal seams are generally developed in the Middle Jurassic system, and low-resistivity coal seams form strong reflection interfaces with surrounding rocks. The overlying Cretaceous system and underlying Triassic system develop sandstone and mudstone, and there are multiple sets of sandstone and mudstone interfaces. During the downward propagation of seismic waves, multiple reflections occur between the strong reflection interface of the coal seam and the sandstone and mudstone interface, forming interlayer multiple waves, which interfere with the imaging of effective waves in deep formations, and form false amplitudes and false structures. Therefore, the identification of internal interlayer multiple waves in the formation is very important.

[0003] Multiple waves are divided into near-surface related multiple waves generated in the shallow low-velocity zone and internal interlayer multiple waves generated in the internal interlayer interface according to the position of generation. At present, the commonly recognized method for removing short-period multiple waves generated near the surface is to use predictive deconvolution, and the remaining internal interlayer multiple waves in the formation are difficult to identify and remove, which is also the focus of geophysics. The methods for identifying internal interlayer multiple waves on the ground seismic data include: in processing, mainly using the time difference between multiple waves and effective waves to identify multiple waves, but it is difficult to identify interlayer multiple waves with similar time differences; in interpretation, using structural similarity to identify multiple waves, but it is difficult to identify multiple waves with similar background formation occurrences. Other methods for identifying multiple waves on the ground seismic data also have their own limitations.

[0004] VSP data, as a bridge between logging and seismic, has received more and more attention in recent years, and one of its important roles is to identify interlayer multiple waves. Unlike the ground shooting and ground receiving observation method of ground seismic, VSP belongs to ground shooting and well receiving, and this observation method determines that the wave field received by VSP is more than that of ground seismic. Not only can upgoing waves be received, but also downgoing waves can be received. The received upgoing waves include upgoing primary waves and upgoing multiple waves, and the received downgoing waves include downgoing primary waves and downgoing multiple waves. The downgoing primary wave is the first arrival wave and is used to calculate the VSP layer velocity. The downgoing multiple wave is the downgoing wave except the downgoing primary wave. The upgoing primary wave is the wave that can intersect with the downgoing primary wave. The upgoing multiple wave is the wave that cannot intersect with the downgoing primary wave. VSP full wave field data includes upgoing waves and downgoing waves, which appear as cross-shaped on the profile with the horizontal coordinate being the depth of the receiving point and the vertical coordinate being the delay time of the receiving point. The upgoing wave and the downgoing wave appear in a cross shape. The rich wave field data of VSP data can be used to identify multiple waves and the geological interface where the multiple waves are generated.

[0005] However, at present, the industry only uses single VSP wave field data or corridor stack data to identify multiple waves, and the identification result is single, which cannot serve the subsequent processing of ground seismic data. SUMMARY

[0006] Therefore, the embodiments of the present application propose a method, device, equipment and readable medium for identifying internal interbed multiple waves, which perform predictive deconvolution and moveout correction on zero-offset VSP data, identify the upper and lower interfaces and the development position of interbed multiple waves by using the intersection relationship between upgoing waves and downgoing waves on the processed wave field, and calibrate the internal interbed multiple waves of surface seismic, so as to provide accurate information of the interface and the development position of interbed multiple waves for subsequent suppression of the internal interbed multiple waves of surface seismic.

[0007] To achieve the above object, in one aspect, the embodiments of the present application provide a method for identifying internal interbed multiple waves, which comprises the following steps: pre-processing zero-offset VSP data, and eliminating short-period multiple waves related to near surface by deconvolution processing to obtain upgoing wave moveout gathers and downgoing wave moveout gathers containing only internal interbed multiple waves of strata; finding a point of horizontal homodromous axis interruption of upgoing waves in the upgoing wave moveout gathers as a first-order upgoing interruption point, finding a point of downgoing wave interruption at the first-order upgoing interruption point in the downgoing wave moveout gathers along the direction of decreasing time of the downgoing wave, and setting the first-order upgoing interruption point as a reference point; finding a point of downgoing wave interruption at the reference point in the downgoing wave moveout gathers along the direction of decreasing depth of the upgoing wave, finding a point of upgoing wave interruption at the current-order downgoing interruption point in the upgoing wave moveout gathers along the direction of increasing time of the downgoing wave, and setting the current-order upgoing interruption point as a reference point; and repeating the above step to obtain all current-order upgoing interruption points and all current-order downgoing interruption points, obtaining the time of a first-order / current-order interbed multiple wave and the time of a lower interface generating the first-order / current-order interbed multiple wave based on the first-order / current-order upgoing interruption point, and obtaining the time of an upper interface generating the first-order / current-order interbed multiple wave based on the first-order / current-order downgoing interruption point.

[0008] In some embodiments, the method further comprises: performing shear wave removal processing on the VSP data to obtain the zero-offset VSP data.

[0009] In some embodiments, the pre-processing of the zero-offset VSP data comprises: splicing different well sections, denoising and amplitude decay compensation processing of the zero-offset VSP data.

[0010] In some embodiments, the eliminating short-period multiples related to near-surface by deconvolution processing to obtain the up-going and down-going wave motion corrected gathers containing only interbed multiples inside the formation comprises: performing up-down wave field separation on the pre-processed data to obtain up-going and down-going wave gathers; extracting a predictive deconvolution operator in the down-going wave gathers, and performing deconvolution processing on the up-going and down-going wave gathers respectively based on the predictive deconvolution operator to obtain up-going and down-going deconvolution gathers; performing NMO correction on the up-going and down-going deconvolution gathers respectively to obtain up-going and down-going wave motion corrected gathers.

[0011] In some embodiments, the method further comprises: picking first break times of the pre-processed data to calculate VSP interval velocities; performing NMO correction on the up-going and down-going deconvolution gathers respectively based on the VSP interval velocities to obtain up-going and down-going wave motion corrected gathers.

[0012] In some embodiments, the obtaining the time at which the first-order / current-order interbed multiple exists and the time at which the lower interface generating the first-order / current-order interbed multiple exists based on the first-order / current-order up-going break point comprises: obtaining a time corresponding to the first-order / current-order up-going break point to obtain the time at which the first-order / current-order interbed multiple exists, and obtaining a time corresponding to a down-going primary wave having the same depth as the first-order / current-order up-going break point to obtain the time at which the lower interface generating the first-order / current-order interbed multiple exists.

[0013] In some embodiments, the obtaining the time at which the first-order / current-order interbed multiple exists and the time at which the lower interface generating the first-order / current-order interbed multiple exists based on the first-order / current-order up-going break point comprises: obtaining a time corresponding to the first-order / current-order up-going break point to obtain the time at which the first-order / current-order interbed multiple exists, and obtaining a time corresponding to a down-going primary wave having the same depth as the first-order / current-order up-going break point to obtain the time at which the lower interface generating the first-order / current-order interbed multiple exists.

[0014] Another aspect of the embodiment of the present application also provides a device for identifying internal interbed multiple waves, comprising: a preprocessing module configured to preprocess zero-offset VSP data and eliminate short-period multiples related to near surface through deconvolution processing to obtain upgoing wave moveout gather and downgoing wave moveout gather containing only internal interbed multiple waves of strata; a first identification module configured to find a point of upgoing wave horizontal homodromic axis interruption in the upgoing wave moveout gather as a first-order upgoing interruption point, find a point of downgoing wave interruption in the downgoing wave moveout gather along a downgoing wave direction decreasing in time at the first-order upgoing interruption point as a first-order downgoing interruption point, and set the first-order upgoing interruption point as a reference point; a second identification module configured to find a point of downgoing wave interruption in the downgoing wave moveout gather along an upgoing wave direction decreasing in depth at the reference point as a current-order downgoing interruption point, find a point of upgoing wave interruption in the upgoing wave moveout gather along a downgoing wave direction increasing in time at the current-order downgoing interruption point as a current-order upgoing interruption point, and set the current-order upgoing interruption point as the reference point; and a loop module configured to repeat the steps of the second identification module to obtain all current-order upgoing interruption points and all current-order downgoing interruption points, and obtain a time of a first-order / current-order interbed multiple wave and a time of a lower interface generating the first-order / current-order interbed multiple wave based on the first-order / current-order upgoing interruption point, and obtain a time of an upper interface generating the first-order / current-order interbed multiple wave based on the first-order / current-order downgoing interruption point.

[0015] Still another aspect of the embodiment of the present application also provides a computer device, comprising: at least one processor; and a memory storing computer instructions executable on the processor, the instructions being executed by the processor to implement the steps of the above method.

[0016] Still another aspect of the embodiment of the present application also provides a computer readable storage medium storing a computer program which is executed by a processor to implement the steps of the above method.

[0017] The present application has at least the following beneficial technical effects: the zero-offset VSP data is processed through prediction deconvolution and moveout correction, the upper and lower interfaces generating interbed multiple waves and the development positions of the interbed multiple waves are identified on the processed wave field by using the intersection relationship of upgoing waves and downgoing waves, which are used for calibrating internal interbed multiple waves of surface seismic, thereby providing accurate interface generating interbed multiple waves and development position of multiple waves and other information for subsequent suppression of internal interbed multiple waves of surface seismic. BRIEF DESCRIPTION OF DRAWINGS

[0018] In order to make the objectives, technical solutions and advantages of the present application clearer, the following will further describe the embodiments of the present application with reference to the accompanying drawings.

[0019] Figure 1 A schematic diagram of an embodiment of the method for identifying internal interbed multiple waves provided by the present application;

[0020] Figure 2 A schematic diagram of the preprocessed VSP full wave field data;

[0021] Figure 3 A schematic diagram of VSP first arrival picking and layer velocity calculation;

[0022] Figure 4 A schematic diagram of a predictive deconvolution operator;

[0023] Figure 5 (a) A schematic diagram of a downgoing wave moveout corrected gather;

[0024] Figure 5 (b) A schematic diagram of an upgoing wave moveout corrected gather;

[0025] Figure 6 A schematic diagram of an embodiment of the device for identifying internal interbed multiple waves provided by the present application;

[0026] Figure 7 A schematic diagram of an embodiment of the computer device provided by the present application;

[0027] Figure 8 A schematic diagram of an embodiment of the computer readable storage medium provided by the present application. DETAILED DESCRIPTION

[0028] In order to make the objectives, technical solutions and advantages of the present application clearer, the following will further describe the embodiments of the present application with reference to the accompanying drawings.

[0029] It should be noted that all the expressions of "first" and "second" in the embodiments of the present application are used to distinguish two same name different entities or different parameters, and it can be seen that "first" and "second" are only for the convenience of description, and should not be understood as a limitation of the embodiments of the present application. The subsequent embodiments will not be described one by one.

[0030] Based on the above purpose, the first aspect of the embodiments of the present application proposes an embodiment of the method for identifying internal interbed multiple waves. Figure 1An embodiment of the method for identifying internal interbed multiple provided by the application is shown. Figure 1 The method for identifying internal interbed multiple of the embodiment of the application comprises the following steps:

[0031] 001, pre-process the zero-offset VSP data, and eliminate the short-period multiple related to near-surface by deconvolution processing to obtain upgoing and downgoing wave moveout gathers containing only internal interbed multiple of stratum;

[0032] 002, find the point of upgoing wave horizontal homodromous axis interruption in the upgoing wave moveout gather as a first-order upgoing interruption point, and find the point of downgoing wave interruption in the downgoing wave moveout gather along the direction of decreasing downgoing wave time at the first-order upgoing interruption point as a first-order downgoing interruption point, and set the first-order upgoing interruption point as a reference point;

[0033] 003, find the point of downgoing wave interruption in the downgoing wave moveout gather along the direction of decreasing upgoing wave depth at the reference point as a current-order downgoing interruption point, and find the point of upgoing wave interruption in the upgoing wave moveout gather along the direction of increasing downgoing wave time at the current-order downgoing interruption point as a current-order upgoing interruption point, and set the current-order upgoing interruption point as a reference point; and

[0034] 004, repeat the previous step to obtain all current-order upgoing interruption points and all current-order downgoing interruption points, and obtain the time of first-order / current-order interbed multiple and the time of lower interface generating first-order / current-order interbed multiple based on the first-order / current-order upgoing interruption point, and obtain the time of upper interface generating first-order / current-order interbed multiple based on the first-order / current-order downgoing interruption point.

[0035] In the embodiment, the zero-offset VSP full-field wave data is pre-processed, wave field is separated, deconvolution and move correction are processed to obtain upgoing and downgoing wave moveout gathers, which are combined to identify internal interbed multiple of stratum, and the steps are as follows: (1) identifying the time of first-order interbed multiple; (2) identifying the time of lower interface generating first-order interbed multiple; (3) identifying the time of upper interface generating first-order interbed multiple; (4) identifying the time of upper interface generating second-order interbed multiple; (5) identifying the time of second-order interbed multiple; (6) identifying the time of lower interface generating second-order interbed multiple; repeating steps (4)-(6) to obtain the time of all-order interbed multiple and the time of upper and lower interfaces generating each-order interbed multiple.

[0036] In the embodiment, the VSP upgoing wave moveout gathers and downgoing wave moveout gathers are used to identify the interbed multiple waves in the formation, including: finding the place where the upgoing wave horizontal homodromous axis is interrupted in the upgoing wave moveout gathers, the time of the interrupted place is the time of the first-order interbed multiple wave, and the time of the downgoing primary wave corresponding to the depth of the interrupted place is the time of the lower interface of the first-order interbed multiple wave; in the downgoing wave moveout gathers, finding the place where the downgoing wave is interrupted from the place where the upgoing wave is interrupted in the direction of decreasing time, the time of the downgoing primary wave corresponding to the depth of the interrupted place is the time of the upper interface of the first-order interbed multiple wave, and the time of the interrupted place is the time of the primary wave reflection interface; in the downgoing wave moveout gathers, finding the place where the downgoing wave is interrupted from the place where the upgoing wave is interrupted in the direction of decreasing depth along the isochronous direction, the time of the downgoing primary wave corresponding to the depth of the interrupted place is the time of the upper interface of the second-order interbed multiple wave; in the upgoing wave moveout gathers, finding the place where the upgoing wave is interrupted from the place where the downgoing wave is interrupted in the direction of increasing time, the time of the interrupted place is the time of the second-order interbed multiple wave, and the time of the downgoing primary wave corresponding to the depth of the interrupted place is the time of the lower interface of the second-order interbed multiple wave; repeating the above two steps to obtain the time of all the interbed multiple waves and the time of the upper and lower interfaces of each interbed multiple wave, and completing the whole process of identifying the interbed multiple waves by using the zero-offset VSP data to assist the identification of the interbed multiple waves on the ground.

[0037] In some embodiments of the present application, the method further comprises: removing the transverse wave to obtain the zero-offset VSP data.

[0038] In the embodiment, the VSP data collected in the field is separated into Z component data after coordinate rotation.

[0039] In some embodiments of the present application, the preprocessing of the zero-offset VSP data comprises: splicing different well sections, denoising and amplitude decay compensation of the zero-offset VSP data.

[0040] In the embodiment, the data is spliced, denoised and amplitude compensated to obtain the preprocessed VSP full wave field data, as shown in FIG. 1, wherein the vertical coordinate is time and the horizontal coordinate is depth. The downgoing wave is the wave in the direction of increasing time with the increase of depth, the downgoing primary wave is the first arrival wave, and the rest are downgoing multiple waves. The upgoing wave is the wave in the direction of decreasing time with the increase of depth, the upgoing primary wave intersects with the downgoing primary wave, and the upgoing multiple wave does not intersect with the downgoing primary wave. Figure 2

[0041] ​In some embodiments of the present application, the elimination of short-period multiples related to near-surface by deconvolution processing to obtain up-going and down-going wave motion corrected gathers containing only inter-bed multiples in the interior of the formation includes: performing up-and down-going wave field separation on the pre-processed data to obtain up-going and down-going gathers; extracting a predictive deconvolution operator in the down-going gathers and performing deconvolution processing on the up-going and down-going gathers based on the predictive deconvolution operator to obtain up-going and down-going deconvolution gathers; performing NMO correction on the up-going and down-going deconvolution gathers respectively to obtain up-going and down-going wave motion corrected gathers.

[0042] In some embodiments of the present application, the method further includes: picking the first arrival time of the pre-processed data to calculate VSP interval velocity; performing NMO correction on the up-going and down-going deconvolution gathers based on the VSP interval velocity to obtain up-going and down-going wave motion corrected gathers.

[0043] In the present embodiment, the first arrival is picked from the pre-processed zero-offset VSP full wave field data, and the VSP interval velocity is calculated based on the relationship between the depth and time of the first arrival; the pre-processed zero-offset VSP full wave field data is separated into up-going and down-going gathers; a predictive deconvolution operator is extracted from the down-going gathers and applied to the up-going and down-going gathers after wave field separation to obtain up-going and down-going deconvolution gathers, in which the short-period multiples related to near-surface are eliminated and only the inter-bed multiples in the interior of the formation are left; NMO correction is performed on the up-going and down-going deconvolution gathers based on the VSP interval velocity to obtain NMO corrected up-going and down-going wave motion corrected gathers for identifying inter-bed multiples.

[0044] In the present embodiment, Figure 3 Shown are the time-depth relationship of VSP picked first arrival and the calculated VSP interval velocity curve, which is obtained from the time-depth relationship. Figure 4 Shown are the predictive deconvolution operators extracted from the down-going data after wave field separation, the purpose of the predictive deconvolution is to eliminate the short-period multiples related to near-surface in the zero-offset VSP full wave field data and leave only the inter-bed multiples in the interior of the formation. Figure 5 (a) and Figure 5 (b) respectively show the VSP down-going and up-going wave motion corrected gathers after predictive deconvolution.

[0045] In some embodiments of the present application, obtaining the time at which the first-order / current-order interbedded multiple exists and the time at which the lower boundary surface of the first-order / current-order interbedded multiple exists based on the first-order / current-order uplink breakpoint comprises: obtaining the time corresponding to the downlink primary wave at the same depth as the first-order / current-order uplink breakpoint to obtain the time at which the first-order / current-order interbedded multiple exists.

[0046] In some embodiments of the present application, obtaining the time at which the upper boundary surface of the first-order / current-order interbedded multiple exists based on the first-order / current-order downlink breakpoint comprises: obtaining the time corresponding to the downlink primary wave at the same depth as the first-order / current-order downlink breakpoint to obtain the time at which the upper boundary surface of the first-order / current-order interbedded multiple exists.

[0047] The specific embodiments of the present application are further described below according to specific embodiments. A test of identifying interbedded multiples in a formation is carried out in the abdominal region of the Junggar Basin. The Jurassic system in the abdominal region of the Junggar Basin develops a strong coal seam reflection interface, and interbedded multiples can be generated with the reflection interfaces of the upper and lower formations, but it is difficult to identify interbedded multiples with small primary wave time difference by using only seismic data.

[0048] In the present embodiment, the rich wave field data received by the zero-offset VSP can not only accurately identify the time at which each interbedded multiple exists, which is equivalent to the time of the surface seismic multiple, but also identify the upper and lower boundary surfaces of the interbedded multiple, thereby providing accurate basic information for subsequent seismic multiple suppression.

[0049] Reference Figure 5 (a) and Figure 5 (b), the place where the horizontal homodromous axis of the uplink wave is interrupted on the uplink wave moveout gather is the first-order uplink breakpoint A1, the time corresponding to the first-order uplink breakpoint A1 is the time at which the first-order interbedded multiple exists, and the time a1 of the downlink primary wave corresponding to the depth of the first-order uplink breakpoint A1 is the time at which the lower boundary surface of the first-order interbedded multiple exists; on the downlink wave moveout gather, the place where the downlink wave is interrupted in the direction of decreasing time from the first-order uplink breakpoint A1 is the first-order downlink breakpoint B1, the time b1 of the downlink primary wave corresponding to the first-order downlink breakpoint B1 is the time at which the upper boundary surface of the first-order interbedded multiple exists, and the time at which the first-order downlink breakpoint B1 exists is the time at which the primary reflection interface exists.

[0050] In the down-going wave moveout gather, the second-order down-going break point B2 is found along the direction of decreasing depth from the first-order up-going break point A1, the time b2 of the down-going primary wave corresponding to the second-order down-going break point B2 is the time at which the upper boundary of the second-order interbed multiple is located; in the up-going wave moveout gather, the second-order up-going break point A2 is found along the direction of increasing time from the second-order down-going break point B2, the time of the second-order up-going break point A2 is the time at which the second-order interbed multiple is located, and the time a2 of the down-going primary wave corresponding to the second-order up-going break point A2 is the time at which the lower boundary of the second-order interbed multiple is located. The above steps are repeated to obtain the time at which the third-order interbed multiple is located and the time at which the upper and lower boundaries of each order interbed multiple are located.

[0051] It should be particularly pointed out that each step in each embodiment of the above-mentioned method for identifying internal interbed multiples can be crossed, replaced, added, deleted and reduced, and thus, these reasonable permutations and combinations of the method for identifying internal interbed multiples should also belong to the protection scope of the present application, and the protection scope of the present application should not be limited to the embodiments.

[0052] Based on the above purpose, a second aspect of the embodiments of the present application provides a device for identifying internal interbed multiples. Figure 6 The device for identifying internal interbed multiples provided by the present application is shown in the schematic diagram of the embodiment of the device for identifying internal interbed multiples provided by the present application. Figure 6As shown, the device for identifying internal interlayer multiple waves in the embodiment of the present application comprises the following modules: a preprocessing module 011 configured to preprocess the zero-offset VSP data, and eliminate short-period multiples related to near surface by deconvolution processing to obtain upgoing wave moveout gathers and downgoing wave moveout gathers containing only internal interlayer multiple waves; a first identification module 012 configured to find a point of upgoing wave horizontal homodromous axis interruption in the upgoing wave moveout gathers as a first-order upgoing interruption point, find a point of downgoing wave interruption in the downgoing wave moveout gathers along a direction of decreasing downgoing wave time at the first-order upgoing interruption point as a first-order downgoing interruption point, and set the first-order upgoing interruption point as a reference point; a second identification module 013 configured to find a point of downgoing wave interruption in the downgoing wave moveout gathers along a direction of decreasing upgoing wave time at the reference point as a current-order downgoing interruption point, find a point of upgoing wave interruption in the upgoing wave moveout gathers along a direction of increasing downgoing wave time at the current-order downgoing interruption point as a current-order upgoing interruption point, and set the current-order upgoing interruption point as the reference point; and a loop module 014 configured to repeat the steps of the second identification module 013 to obtain all current-order upgoing interruption points and all current-order downgoing interruption points, and obtain a time of a first-order / current-order interlayer multiple wave and a time of a lower boundary interface generating the first-order / current-order interlayer multiple wave based on the first-order / current-order upgoing interruption point, and obtain a time of an upper boundary interface generating the first-order / current-order interlayer multiple wave based on the first-order / current-order downgoing interruption point.

[0053] Based on the above purpose, a third aspect of the embodiment of the present application provides a computer device. Figure 7 As shown in the schematic diagram of the embodiment of the computer device provided by the present application, Figure 7 As shown, the computer device in the embodiment of the present application comprises the following devices: at least one processor 021; and a memory 022, the memory 022 storing computer instructions 023 executable on the processor, the instructions being executed by the processor to implement the steps of the above method.

[0054] The present application also provides a computer readable storage medium. Figure 8 As shown in the schematic diagram of the embodiment of the computer readable storage medium provided by the present application, Figure 8 As shown, the computer readable storage medium 031 stores a computer program 032 which is executed by the processor to execute the above method.

[0055] Finally, it needs to be explained that all or part of the processes in the above-mentioned embodiment methods can be implemented by a computer program to instruct relevant hardware, and the program of the method of identifying internal interlayer multiples can be stored in a computer-readable storage medium. When the program is executed, it can include the processes of the above-mentioned embodiment methods. The storage medium of the program can be a magnetic disc, an optical disc, a read-only memory (ROM) or a random access memory (RAM), etc. The above-mentioned computer program embodiments can achieve the same or similar effects as the corresponding any method embodiments.

[0056] In addition, the method disclosed in the embodiments of the present application can also be implemented as a computer program executed by a processor, which can be stored in a computer-readable storage medium. When the computer program is executed by the processor, the above-mentioned functions defined in the method disclosed in the embodiments of the present application are performed.

[0057] In addition, the above-mentioned method steps and system units can also be implemented by using a controller and a computer-readable storage medium for storing a computer program for enabling the controller to implement the above-mentioned steps or unit functions.

[0058] Those skilled in the art will also appreciate that the various illustrative logical blocks, modules, circuits, and algorithm steps described in connection with the disclosure herein can be implemented as electronic hardware, computer software, or combinations of both. To clearly illustrate this interchangeability of hardware and software, various illustrative components, blocks, modules, circuits, and steps have been described generally in terms of their functionality. Whether such functionality is implemented as hardware or software depends on the particular application and design constraints imposed on the overall system. Skilled persons can implement the functions in various ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the embodiments disclosed herein.

[0059] In one or more exemplary designs, the functions described can be implemented in hardware, software, firmware, or any combination thereof. If implemented in software, the functions can be stored on or transmitted over as one or more instructions or code on a computer-readable medium. Computer-readable media includes both computer storage media and communication media including any medium that facilitates transfer of a computer program from one place to another. A storage media can be any available media that can be accessed by a general purpose or special purpose computer. By way of example, and not limitation, such computer-readable media can comprise RAM, ROM, EEPROM, CD-ROM or other optical disk storage, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to carry or store desired program code means in the form of instructions or data structures and that can be accessed by a general-purpose or special-purpose computer, or a general-purpose or special-purpose processor. Also, any connection is properly termed a computer-readable medium. For example, if the software is transmitted from a website, server, or other remote source using a coaxial cable, fiber optic cable, twisted pair, digital subscriber line (DSL), or other wire-based, fiber-based, or wireless technologies, then the coaxial cable, fiber optic cable, twisted pair, DSL, or other wire-based, fiber-based, or wireless technologies are included in the definition of medium. Disk and disc, as used herein, includes compact disc (CD), laser disc, optical disc, digital versatile disc (DVD), floppy disk and blu-ray disc where disks usually reproduce data magnetically, while discs reproduce data optically with lasers. Combinations of the above should also be included within the scope of computer-readable media.

[0060] The foregoing is a summary of the example embodiments disclosed herein, but it should be noted that various changes and modifications can be made without departing from the scope of the embodiments disclosed by the claims. The functions, steps and / or actions of the method claims described herein need not be performed in any particular order. Furthermore, although elements of the embodiments disclosed herein can be described or claimed in individual form, other embodiments can also include a plurality of those elements in combination.

[0061] It should be understood that, as used herein, "a" or "an" can mean one or more things unless context clearly indicates otherwise. It should also be understood that "and / or" as used herein means any and all possible combinations of one or more of the associated listed items.

[0062] The above-mentioned example embodiment numbers of the embodiments disclosed herein are merely for description, and do not represent the advantages or disadvantages of the embodiments.

[0063] Those skilled in the art can understand that all or part of the steps of the above-mentioned embodiments can be completed by hardware, or by program instructing relevant hardware to complete, and the program can be stored in a computer readable storage medium. The storage medium mentioned above can be a read-only memory, a magnetic disk or an optical disk, etc.

[0064] Those skilled in the art shall understand that the above discussion of any embodiment is only exemplary, and is not intended to imply that the scope (including claims) of the embodiments of the present application is limited to these examples; the technical features in the above embodiments or different embodiments can also be combined, and there are many other changes of different aspects of the embodiments of the present application as above. In order to be brief, they are not provided in details. Therefore, any omission, modification, equivalent replacement, improvement, etc. made in the spirit and principle of the embodiments of the present application shall be included in the protection scope of the embodiments of the present application.

Claims

1. A method for identifying internal interlayer multiples, characterized in that, Includes the following steps: The zero-biased VSP data was preprocessed, and short-period multiples associated with the near-surface were eliminated by deconvolution to obtain up-wave correction sets and down-wave correction sets that only contain inter-layer multiples within the formation. In the uplink wave correction channel set, the point where the horizontal axis of the uplink wave is interrupted is identified as the first-order uplink interruption point. In the downlink wave correction channel set, the point where the downlink wave is interrupted along the time-decreasing direction of the downlink wave at the first-order uplink interruption point is identified as the first-order downlink interruption point. The first-order uplink interruption point is set as the reference point. At the reference point in the downlink fluctuation correction set, find the point where the downlink wave is interrupted along the direction of decreasing depth of the uplink wave as the current downlink interruption point. At the current downlink interruption point in the uplink fluctuation correction set, find the point where the uplink wave is interrupted along the direction of increasing time of the downlink wave as the current uplink interruption point. Set the current uplink interruption point as the reference point. as well as Repeat the previous step to obtain all current-order uplink interruption points and all current-order downlink interruption points. Based on the first-order / current-order uplink interruption points, obtain the time of occurrence of the first-order / current-order inter-wavelength multiples and the time of occurrence of the lower interface of the first-order / current-order inter-wavelength multiples. Based on the first-order / current-order downlink interruption points, obtain the time of occurrence of the upper interface of the first-order / current-order inter-wavelength multiples. Short-period multiples associated with the near-surface are eliminated through deconvolution processing to obtain up-wave correction sets and down-wave correction sets containing only intra-stratum interlayer multiples. The preprocessed data is subjected to uplink and downlink wave field separation to obtain uplink channel sets and downlink channel sets; A predictive deconvolution operator is extracted from the downlink channel set, and deconvolution processing is performed on the uplink channel set and the downlink channel set based on the predictive deconvolution operator to obtain the uplink deconvolution channel set and the downlink deconvolution channel set; Dynamic corrections are performed on the uplink deconvolution gather and the downlink deconvolution gather, respectively, to obtain the uplink fluctuation correction gather and the downlink fluctuation correction gather; The first arrival time of the preprocessed data is picked up to calculate the VSP layer velocity; Based on the VSP layer velocity, dynamic corrections are performed on the uplink deconvolution gather and the downlink deconvolution gather to obtain the uplink fluctuation correction gather and the downlink fluctuation correction gather.

2. The method for identifying internal interlayer multiples according to claim 1, characterized in that, Also includes: Shear wave removal is performed on the VSP data to obtain zero-bias VSP data.

3. The method for identifying internal interlayer multiples according to claim 1, characterized in that, Preprocessing of zero-bias VSP data includes: The zero-bias VSP data was spliced ​​from different well sections, denoised, and subjected to amplitude attenuation compensation.

4. The method for identifying internal interlayer multiples according to claim 1, characterized in that, The time of the first-order / current-order inter-level multiple wave generation and the time of the generation of the lower interface of the first-order / current-order inter-level multiple wave generation are obtained based on the first-order / current-order uplink interruption point, including: Obtain the time corresponding to the first-order / current-order uplink interruption point to obtain the time of the first-order / current-order inter-wave multiples, and obtain the time corresponding to the downlink primary wave with the same depth as the first-order / current-order uplink interruption point to obtain the time of the lower interface where the first-order / current-order inter-wave multiples are generated.

5. The method for identifying internal interlayer multiples according to claim 1, characterized in that, Based on the aforementioned first-order / current-order downlink interruption point, the times at which multiple wave interfaces between the first-order / current-order levels are generated include: Obtain the time corresponding to the first wave at the same depth as the first / current order downlink interruption point to obtain the time when the interface of multiple waves between the first / current order is generated.

6. A device for identifying internal interlayer multiples, characterized in that, include: The preprocessing module is configured to preprocess the zero-bias VSP data and eliminate short-period multiples associated with the near-surface through deconvolution processing to obtain an up-wave correction set and a down-wave correction set that only contain inter-layer multiples within the strata. The first identification module is configured to find the point where the horizontal axis of the upward wave is interrupted in the upward wave correction channel set as the first-order upward interruption point, and to find the point where the downward wave is interrupted along the time-decreasing direction of the downward wave at the first-order upward interruption point in the downward wave correction channel set as the first-order downward interruption point, and to set the first-order upward interruption point as the reference point. The second identification module is configured to find the point where the downwave is interrupted along the direction of decreasing depth of the upwave at the reference point in the downwave correction set as the current downwave interruption point, and to find the point where the upwave is interrupted along the direction of increasing time of the downwave at the current downwave interruption point in the upwave correction set as the current upwave interruption point, and to set the current upwave interruption point as the reference point. as well as The loop module is configured to repeat the steps of the second identification module to obtain all current-order uplink interruption points and all current-order downlink interruption points. Based on the first-order / current-order uplink interruption points, it obtains the time of the first-order / current-order inter-wavelength multiples and the time of the generation of the lower interface of the first-order / current-order inter-wavelength multiples. Based on the first-order / current-order downlink interruption points, it obtains the time of the generation of the upper interface of the first-order / current-order inter-wavelength multiples. The preprocessing module is configured to: The preprocessed data is subjected to uplink and downlink wave field separation to obtain uplink channel sets and downlink channel sets; A predictive deconvolution operator is extracted from the downlink channel set, and deconvolution processing is performed on the uplink channel set and the downlink channel set based on the predictive deconvolution operator to obtain the uplink deconvolution channel set and the downlink deconvolution channel set; Dynamic corrections are performed on the uplink deconvolution gather and the downlink deconvolution gather, respectively, to obtain the uplink fluctuation correction gather and the downlink fluctuation correction gather; The first arrival time of the preprocessed data is picked up to calculate the VSP layer velocity; Based on the VSP layer velocity, dynamic corrections are performed on the uplink deconvolution gather and the downlink deconvolution gather to obtain the uplink fluctuation correction gather and the downlink fluctuation correction gather.

7. A computer device, characterized in that, include: At least one processor; as well as A memory storing computer instructions executable on the processor, which, when executed by the processor, implement the steps of the method according to any one of claims 1-5.

8. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by a processor, it implements the steps of the method according to any one of claims 1-5.

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