Method and device for determining seismic observation system based on node instrument

Abstract

The invention provides a node instrument-based seismological observation system determination method and apparatus. The node instrument-based seismological observation system determination method comprises the steps of converting pre-acquired original shot point data into transition shot point data according to a preset first data format; wherein the first data format at least comprises a shot point station number; converting pre-acquired original detection point data into transition detection point data according to a preset second data format; the second data format at least comprises a detection point station number; and determining the seismological observation system according to the original shot point data, the original detection point data, the transition shot point data and the transition detection point data. According to the method, the seismic data observation system can be quickly determined and the quality control and processing of the acquired data can be carried out in real time under the condition that the node instrument acquired data has no relation file, so that the quality of the acquired data is ensured and the processing efficiency is accelerated.

Description

Technical Field

[0001] This application belongs to the technical field of oil and gas exploration, especially the technical field of seismic data acquisition and processing in geophysical exploration. Specifically, it relates to a method and device for determining a seismic observation system based on nodal instruments. Background Art

[0002] The determination of an observation system generally involves the instrument department reporting and defining a geometry library to establish the corresponding relationship between shot points and receiving points. The purpose of defining an observation system is to identify all the points involved in the work area: shot points, geophone points, CMP points (bin) with a unique number (station number), and determine the arrangement pattern of shot points and geophone points as well as the coverage times.

[0003] In the prior art, a relatively mature way to define an observation system is that the acquisition personnel provide regular SPS (Shell Procession Support Format) files, namely the shot point file S file, the geophone point file R file, and the relationship file X file.

[0004] The SPS format was initially created by Shell to establish a set of general standards for inputting other construction parameters such as surveying and shot points into the acquisition system, so as to achieve the integration of receiving and excitation factors related to the acquired data and data related to seismic exploration and send them to the seismic data processing center. During the production process, SPS, as the first step in the quality control of acquired data, can minimize construction errors.

[0005] Composition of the SPS system: The SPS system consists of two sets of input and output files

[0006] (1) Input files: A total of four files S, R, X, and T are included, which are input into the seismograph system by the instrument operator.

[0007] The S file contains the coordinates, elevation, and related information of the shot points; the R file contains the coordinates, elevation, and related information of the receiving points;

[0008] The X file contains the corresponding relationship information between each shot point and the receiving point; the T file contains other input parameters defined by the user.

[0009] (2) Output files include the following types of files:

[0010] SPS files (S, R, X, T): Are updated and output daily during production, used for the first step of quality control, checking the shot-geophone relationship, modifying errors, and provided to the data processing center for data interpretation. They are the most important files.

[0011] APS files and other source state data files: Used to output shot point results during source construction, including various data such as distortion, phase, output, coordinates, etc. of each source in each acquisition.

[0012] SPS-like files for receiver point quality: Used for geophone pulse and resistance result analysis.

[0013] SPS-like files for field unit history: Used to find lost field units.

[0014] Based on the SPS files, the processing personnel can quickly and conveniently obtain information such as the shot point and geophone point station numbers, coordinates, elevations, etc. for each shot and each trace, and define the acquisition system. However, with the transformation of the acquisition method, that is, from "cabled" to "node", the acquisition system changes from "regular" to "irregular", and the acquired data changes to full space-time and full wavelength, the corresponding processing technology needs to change. The data received by traditional "cabled" geophones is a complete single shot with a regular acquisition system. At the end of the day's acquisition, complete data and a regular SPS file can be obtained, that is, the number of traces corresponding to each shot is fixed, and the number of arrays is also fixed. However, it is difficult to obtain a complete SPS file in real time for the data acquired by "node", especially for the relationship file X file. On the one hand, the "node" acquisition breaks through the limitations of the traditional acquisition system, generally being full-array acquisition, and the received data is for an irregular acquisition system, that is, the number of arrays and traces corresponding to each shot are not fixed. Therefore, it is difficult to quickly obtain the relationship file X file for the shot point and geophone point. On the other hand, a large number of node instruments are required for a work area, and the quantity of a single type of node instrument often cannot meet the needs of a work area. Often, 2 or more types of geophones are used for simultaneous acquisition. However, the numbering of the traces acquired by different geophone points all starts from 1 and cannot be continuously numbered. Therefore, the data acquired by different geophones cannot use the same relationship file, which causes great problems for processing. If the acquisition system is defined according to the traditional SPS file, the processing time will be relatively lagged, and on-site processing quality control cannot be carried out in real time. Summary of the Invention

[0015] The present invention belongs to the technical field of seismic data processing. An object of the present invention is to, for the data acquired by node instruments, determine the acquisition system in real time without a relationship file to improve the quality control efficiency and processing efficiency of the acquired data.

[0016] Another object of the present invention is to provide a determining device for a seismic observation system based on a nodal instrument. Still another object of the present invention is to provide an electronic device, which includes a memory and a processor, the memory stores a computer program, and when the processor executes the computer program, the steps of the above-mentioned determining method for the seismic observation system based on the nodal instrument are implemented. Still another object of the present invention is to provide a readable medium, on which a computer program is stored, and when the computer program is executed by a processor, the steps of the above-mentioned determining method for the seismic observation system based on the nodal instrument are implemented.

[0017] To solve the technical problems in the background art of the present application, the present invention provides the following technical solutions:

[0018] In a first aspect, the present invention provides a determining method for a seismic observation system based on a nodal instrument, including:

[0019] Converting the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number;

[0020] Converting the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes the geophone point station number;

[0021] Determining the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

[0022] In an embodiment of the present invention, a determining method for a seismic observation system based on a nodal instrument further includes:

[0023] Determining the shot point station number of the transitional shot point data according to the shot line number and the shot point number in the original shot point data.

[0024] In an embodiment of the present invention, a determining method for a seismic observation system based on a nodal instrument further includes:

[0025] Determining the geophone point station number of the transitional geophone point data according to the geophone line number and the geophone point number in the original geophone point data.

[0026] In an embodiment of the present invention, the first data format is:

[0027] Shot point station number, identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, elevation.

[0028] In an embodiment of the present invention, the second data format is:

[0029] Geophone point station number, identifier, geophone point X coordinate, geophone point Y coordinate, elevation.

[0030] In an embodiment of the present invention, determining the seismic observation system according to the original shot point data, the original geophone point data, the transition shot point data, and the transition geophone point data includes:

[0031] When the identifier of each trace in the original shot point data and the original geophone point data has a first mapping relationship with the shot point station number and the geophone point station number, determining the first calculation parameter of the seismic observation system according to the original shot point data and the original geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the shot point station number, and the identifier of each trace in the original geophone point data is the geophone point station number;

[0032] Determining the seismic observation system according to the first calculation parameter.

[0033] In an embodiment of the present invention, determining the seismic observation system according to the original shot point data, the original geophone point data, the transition shot point data, and the transition geophone point data further includes:

[0034] When the identifier of each trace in the original shot point data and the original geophone point data has a second mapping relationship with the shot point station number and the geophone point station number, determining the second calculation parameter of the seismic observation system according to the transition shot point data and the transition geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the sum of the shot line number and the shot point number, and the identifier of each trace in the original geophone point data is the sum of the geophone line number and the geophone point number;

[0035] Determining the seismic observation system according to the second calculation parameter.

[0036] In a second aspect, the present invention provides a determining device for a seismic observation system based on a nodal instrument, and the device includes:

[0037] A shot point data conversion module, configured to convert the pre-acquired original shot point data into transition shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number;

[0038] A geophone point data conversion module, configured to convert the pre-acquired original geophone point data into transition geophone point data according to a preset second data format; the second data format at least includes the geophone point station number;

[0039] A seismic observation system determination module, configured to determine the seismic observation system according to the original shot point data, the original geophone point data, the transition shot point data, and the transition geophone point data.

[0040] In an embodiment of the present invention, a determining device for a seismic observation system based on a nodal instrument further includes:

[0041] A shot point station number determining module, configured to determine the shot point station number of the transition shot point data according to the shot line number and the shot point number in the original shot point data.

[0042] In an embodiment of the present invention, a determining device for a seismic observation system based on a nodal instrument further includes:

[0043] A geophone point station number determining module, configured to determine the geophone point station number of the transition geophone point data according to the geophone line number and the geophone point number in the original geophone point data.

[0044] In an embodiment of the present invention, the first data format is:

[0045] Shot point station number, identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, elevation.

[0046] In an embodiment of the present invention, the second data format is:

[0047] Geophone point station number, identifier, geophone point X coordinate, geophone point Y coordinate, elevation.

[0048] In an embodiment of the present invention, the seismic observation system determining module includes:

[0049] A first calculation parameter determining unit, configured to determine the first calculation parameter of the seismic observation system according to the original shot point data and the original geophone point data when the identifier of each trace in the original shot point data and the original geophone point data has a first mapping relationship with the shot point station number and the geophone point station number; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the shot point station number, and the identifier of each trace in the original geophone point data is the geophone point station number;

[0050] A first seismic observation system determining unit, configured to determine the seismic observation system according to the first calculation parameter.

[0051] In an embodiment of the present invention, the seismic observation system determining module further includes:

[0052] A second calculation parameter determination unit, configured to determine a second calculation parameter of the seismic observation system according to the transition shotpoint data and the transition geophone data when the identifier of each trace in the original shotpoint data and the original geophone data has a second mapping relationship with the shotpoint station number and the geophone station number; wherein, the first mapping relationship is that the identifier of each trace in the original shotpoint data is the sum of the shotline number and the shotpoint number, and the identifier of each trace in the original geophone data is the sum of the geophone line number and the geophone point number;

[0053] A seismic observation system determination second unit, configured to determine the seismic observation system according to the second calculation parameter.

[0054] In a third aspect, the present invention provides a computer program product, including a computer program / instructions, which when executed by a processor implement the steps of a method for determining a seismic observation system based on a nodal seismograph.

[0055] In a fourth aspect, the present invention provides an electronic device, including a memory, a processor, and a computer program stored on the memory and executable on the processor, and when the processor executes the program, it implements the steps of a method for determining a seismic observation system based on a nodal seismograph.

[0056] In a fifth aspect, the present invention provides a computer-readable storage medium, on which a computer program is stored, and when the computer program is executed by a processor, it implements the steps of a method for determining a seismic observation system based on a nodal seismograph.

[0057] As can be seen from the above description, the embodiments of the present invention provide a method and apparatus for determining a seismic observation system based on a nodal seismograph. The corresponding method for determining a seismic observation system based on a nodal seismograph includes: first, converting the pre-acquired original shotpoint data into transition shotpoint data according to a preset first data format; wherein, the first data format includes at least the shotpoint station number; then, converting the pre-acquired original geophone data into transition geophone data according to a preset second data format; the second data format includes at least the geophone station number; finally, determining the seismic observation system according to the original shotpoint data, the original geophone data, the transition shotpoint data, and the transition geophone data.

[0058] The corresponding apparatus for determining a seismic observation system based on a nodal seismograph includes: a shotpoint data conversion module, configured to convert the pre-acquired original shotpoint data into transition shotpoint data according to a preset first data format; wherein, the first data format includes at least the shotpoint station number; a geophone data conversion module, configured to convert the pre-acquired original geophone data into transition geophone data according to a preset second data format; the second data format includes at least the geophone station number; a seismic observation system determination module, configured to determine the seismic observation system according to the original shotpoint data, the original geophone data, the transition shotpoint data, and the transition geophone data.

[0059] The method and device for determining a seismic observation system based on a nodal instrument provided by an embodiment of the present invention can quickly determine a seismic data observation system in the case of no relationship file for the data collected by the nodal instrument, and can be applied to on-site forward monitoring and processing of data collected by the nodal instrument. Specifically, the present invention collects given shot point files and geophone point files, reorganizes them into the format of shot point station numbers and geophone point station numbers, corresponding one by one to the shot point station numbers and geophone point station number information in the collected data, reads the information such as shot point and geophone point coordinates and elevations required for processing, quickly determines the observation system, and conducts quality control and processing of the collected data in real time to ensure the quality of the collected data and improve the processing efficiency. BRIEF DESCRIPTION OF THE DRAWINGS

[0060] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the description of the embodiments or the prior art. Obviously, the drawings in the following description are some embodiments of the present invention. For those of ordinary skill in the art, other drawings can be obtained based on these drawings without creative efforts.

[0061] Figure 1 It is a schematic flowchart of a method for determining a seismic observation system based on a nodal instrument in an embodiment of the present invention;

[0062] Figure 2 It is another schematic flowchart of a method for determining a seismic observation system based on a nodal instrument in an embodiment of the present invention;

[0063] Figure 3 It is a third schematic flowchart of a method for determining a seismic observation system based on a nodal instrument in an embodiment of the present invention;

[0064] Figure 4 It is a first schematic flowchart of step 300 of a method for determining a seismic observation system based on a nodal instrument in an embodiment of the present invention;

[0065] Figure 5 It is a second schematic flowchart of step 300 of a method for determining a seismic observation system based on a nodal instrument in an embodiment of the present invention;

[0066] Figure 6 It is a schematic flowchart of a method for determining a seismic observation system based on a nodal instrument in the specific embodiment of the present invention;

[0067] Figure 7 It is a mind map of a method for determining a seismic observation system based on a nodal instrument in the specific embodiment of the present invention;

[0068] Figure 8Schematic diagram of the original shot point file S file in the specific embodiment of the present invention;

[0069] Figure 9 Schematic diagram of the reorganized shot point file S file in the specific embodiment of the present invention;

[0070] Figure 10 Schematic diagram of the original geophone point file R file in the specific embodiment of the present invention;

[0071] Figure 11 Newly reorganized geophone point file R file in the specific embodiment of the present invention;

[0072] Figure 12 Schematic diagram of a single shot after determining the seismic acquisition system in the specific embodiment of the present invention;

[0073] Figure 13 In the specific embodiment of the present invention Figure 12 Schematic diagram of the positional relationship between the shot point and the geophone point corresponding to the single shot after determining the seismic acquisition system;

[0074] Figure 14 Block diagram of the device for determining the seismic acquisition system based on nodal instruments in the specific embodiment of the present invention;

[0075] Figure 15 Schematic diagram of the structure of the electronic device in the embodiment of the present invention. Specific embodiment

[0076] To make the objectives, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are some, but not all, of the embodiments of the present invention. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present invention without creative efforts shall fall within the protection scope of the present invention.

[0077] Those skilled in the art should understand that the embodiments of the present invention can be provided as a method, a system, or a computer program product. Therefore, the present invention can take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware aspects. Moreover, the present invention can take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0078] It should be noted that the terms "including" and "having" and any variations thereof in the description, claims and above-mentioned drawings of this application are intended to cover non-exclusive inclusion. For example, a process, method, system, product or device that includes a series of steps or units does not necessarily limit to those clearly listed steps or units, but may include other steps or units not clearly listed or inherent to these processes, methods, products or devices. Without conflict, the embodiments in this application and the features in the embodiments can be combined with each other. The following will detail this application with reference to the drawings and in combination with the embodiments.

[0079] In the technical solution of this application, the acquisition, storage, use, processing, etc. of data all comply with the relevant regulations of laws and regulations.

[0080] Embodiment 1:

[0081] An embodiment of the present invention provides a specific implementation manner of a method for determining a seismic observation system based on a nodal seismograph. Refer to Figure 1 , and specifically includes the following content:

[0082] Step 100: Convert the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number;

[0083] Step 200: Convert the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes the geophone point station number;

[0084] Step 300: Determine the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

[0085] As can be seen from the above description, an embodiment of the present invention provides a method for determining a seismic observation system based on a nodal seismograph, including: first, convert the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number; then, convert the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes the geophone point station number; finally, determine the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

[0086] The method for determining a seismic observation system based on a nodal seismograph provided by an embodiment of the present invention can quickly determine a seismic data observation system in the case of no relationship file for the data collected by the nodal seismograph, and can be applied to on-site forward monitoring and processing of data collected by the nodal seismograph. Specifically, the present invention collects given shot point files and geophone point files, reorganizes them into the format of shot point station numbers and geophone point station numbers, corresponding one by one to the shot point station numbers and geophone point station numbers in the collected data, reads information such as shot point and geophone point coordinates and elevations required for processing, quickly determines the observation system, and conducts quality control and processing of the collected data in real time to ensure the quality of the collected data and improve the processing efficiency.

[0087] The method for determining a seismic observation system based on a nodal seismograph provided by an embodiment of the present invention provides a reliable quantitative index to analyze the change trend of imaging results of different observation systems, and solves the problem that the subtle differences in imaging results cannot be visually distinguished.

[0088] Embodiment 2:

[0089] Regarding step 100, the shot point data refers to the record of the positions of shot points arranged on the ground or the seabed. In seismic exploration, devices such as blasting sources or vibrating vehicles are usually used to place shot points at different positions and record their position coordinates and detonation times. By controlling the combination of detonation time and spatial position, underground seismic sources can be generated to send seismic waves underground, and then seismic signals such as reflections and refractions of underground strata can be recorded. The shot point data records the position coordinates of each explosion source. These explosion sources generate seismic waves that propagate through different rock layers underground and are reflected or refracted back to the surface. The shot point data records the position information of each shot point, which is used to determine the initial position and propagation path of the seismic waves.

[0090] The shot point station number in the shot point data refers to the unique identifier for numbering or identifying each shot point. The shot point station number can be a number, a letter, or a combination of numbers and letters, used to distinguish different shot points.

[0091] The compilation method of the shot point station number can be different according to actual needs and the regulations of the exploration company. Usually, the shot point station number will be compiled according to a certain rule to facilitate data management and analysis. For example, it can be compiled in the order of geographical location, or according to the needs of the exploration project. The role of the shot point station number is to uniquely identify each shot point, which is convenient for corresponding and tracking during data processing and interpretation. In seismic exploration, the shot point station number is usually stored and used together with other attributes of the shot point data (such as shot point position, seismic source energy, etc.) to provide complete data information.

[0092] Regarding step 200, geophone point data refers to the records of receivers (also known as geophones) arranged on the ground or the seabed. Geophone points are usually arranged in a grid or linear pattern around the shot points, and they record the received seismic wave signals. The seismic signals recorded by geophone points contain information such as reflected signals, refracted signals, and noise signals of the underground strata. Geophone point data and shot point data together constitute the seismic record section, which is used for seismic imaging and geological interpretation.

[0093] The geophone point station number refers to the unique identifier used to number or identify each geophone point. In seismic exploration, the geophone point station number is used to distinguish different geophone point positions and receivers.

[0094] The compilation method of the geophone point station number can vary according to actual needs and the regulations of the exploration company. Usually, the geophone point station number is compiled according to a certain rule to facilitate data management and analysis. For example, it can be compiled in the order of geographical location, or according to the needs of the exploration project.

[0095] The function of the geophone point station number is to uniquely identify each geophone point, facilitating correspondence and tracking during data processing and interpretation. In seismic exploration, the geophone point station number is usually stored and used together with other attributes of the geophone point data (such as geophone point position, seismic signal record, etc.) to provide complete data information.

[0096] For step 300, the seismic observation system refers to the arrangement method that describes the relative spatial position relationship between the excitation points and the receiver point arrangement in seismic exploration. Different seismic exploration methods adopt different observation systems.

[0097] From the perspective of the types of received seismic waves, the observation system can be divided into refraction wave observation system, longitudinal wave observation system, transverse wave observation system, and converted wave observation system; from the perspective of the observation space, it can be divided into two-dimensional seismic observation system and three-dimensional seismic observation system; from the perspective of the observation method, it can be divided into simple continuous observation system and multiple coverage observation system. The choice of which seismic observation system depends on the seismic exploration task, the seismic geological conditions of the exploration area, the data quality, the seismic equipment capabilities, and the exploration cost. For example, in each stage of seismic exploration reconnaissance, general survey, and detailed survey, different observation systems should be selected: in the reconnaissance and general survey stages, mainly two-dimensional seismic observation systems are adopted, and for areas with low signal-to-noise ratio, the number of coverage can be appropriately increased; in the detailed survey stage, mainly three-dimensional seismic observation systems are adopted, and the number of coverage and the bin size are determined by the geological task.

[0098] Whether it is two-dimensional seismic exploration or three-dimensional seismic exploration, a multiple coverage observation system is adopted, and there are three basic types:

[0099] (1) When the excitation point is in the center of the arrangement, it is called a symmetric observation system;

[0100] (2) The excitation point is not in the center of the array, which is called an asymmetric observation system (the number of receiving channels on both sides of the shot point is not equal);

[0101] (3) The shot point at the end point of the array is called a single-side observation system. With the continuous development of seismic exploration technology, the types of seismic observation systems have also become more diverse. For details, see two-dimensional seismic observation system and three-dimensional seismic observation system.

[0102] The basic parameters of the seismic observation system include trace spacing, bins, coverage times, offset distance, shot point spacing, receiving line spacing, and shot line spacing. The observation system is generally represented by a graphical method, mainly the time-distance plane method and the comprehensive plane method. The time-distance plane method is to represent the observation areas corresponding to different shot points in the form of time-distance curves on the plane map. In simple cases, such as when the reflection interface is a single horizontal or inclined surface, the reflected waves from the same interface can be clearly represented, but in a complex observation system, the position of the observation area cannot be correctly reflected. The comprehensive plane method is to represent the relative spatial position relationship between the excitation point and the receiving point, as well as the observed area, on the plane map in the same way as the time-distance plane method. The representation method of the comprehensive plane map is to mark the excitation points and receiving points distributed on the survey line on the survey line according to a certain ratio, and then draw an oblique line at 45 degrees to the survey line from each excitation point to the receiving arrangement direction. This oblique line is called the common shot point line, and then the receiving point is projected onto this oblique line. The projection line from the detection point is called the common receiving point line, and the intersection of the two is called the common reflection point. Then the observation section is the distance between the projection points of different common reflection points to the survey line. The distribution of the shot offset and the number of times each reflection point is covered can be seen from the comprehensive plane map. In two-dimensional seismic exploration, comprehensive plane maps are often used to design and analyze seismic observation systems. In three-dimensional seismic exploration, the three-dimensional observation system usually displays it on the plane according to the coordinates of the shot check points, and the comprehensive plane map is still used to analyze the distribution of the shot offset, azimuth and number of times of coverage of each line in the three-dimensional observation.

[0103] When implementing step 300, it is first necessary to determine the relationship between the identifier of each data in the original shot point data and the shot point station number, as well as the relationship between the identifier of each data in the original detection point data and the detection point station number, and then calculate the calculation parameters of the seismic observation system. Then, the grid operation is loaded based on the calculation parameters, and on this basis, the track distance, surface element, number of coverages, offset distance, shot point distance, receiving line distance, shot line distance and other information are calculated, so as to determine the seismic observation system corresponding to the original shot point data and the original detection point data.

[0104] In some embodiments of the present invention, see Figure 2 , a method for determining a node-based earthquake observation system, further comprising:

[0105] Step 400: Determine the shot point station number of the transitional shot point data according to the shot line number and the shot point number in the original shot point data.

[0106] The shot line number is used to identify the shot point layout line or survey line in seismic exploration. In seismic exploration, shot points are often arranged along one or more lines, which are usually called shot lines. The shot line number is used to uniquely identify each shot line, facilitating data management and analysis. The shot line number is usually a combination of numbers or letters, compiled according to specific exploration projects and company regulations.

[0107] The shot point number is used to identify the position of each specific shot point in seismic exploration. Each shot point has a unique shot point number, which is used to uniquely identify the position information of the shot point. The shot point number is usually a number, compiled in the order of shot point layout. The shot point number can be used in combination with the shot line number to further determine the specific position of the shot point.

[0108] Specifically, calculate the shot point station number of the transitional shot point data according to the following formula:

[0109] Shot point station number = shot line number × 10000 + shot point number;

[0110] Preferably, the letters in the shot line number and the shot point number can be removed.

[0111] In some embodiments of the present invention, refer to Figure 3 , a determination method of a seismic observation system based on a nodal seismograph, further includes:

[0112] Step 500: Determine the geophone point station number of the transitional geophone point data according to the geophone line number and the geophone point number in the original geophone point data.

[0113] The geophone line number is used to identify the geophone point layout line or survey line in seismic exploration. In seismic exploration, geophone points are often arranged along one or more lines, which are usually called geophone lines. The geophone line number is used to uniquely identify each geophone line, facilitating data management and analysis. The geophone line number is usually a combination of numbers or letters, compiled according to specific exploration projects and company regulations.

[0114] The geophone point number is used to identify the position of each specific geophone point in seismic exploration. Each geophone point has a unique geophone point number, which is used to uniquely identify the position information of the geophone point. The geophone point number is usually a number, compiled in the order of geophone point layout. The geophone point number can be used in combination with the geophone line number to further determine the specific position of the geophone point.

[0115] Specifically, calculate the geophone point station number of the transitional shot point data according to the following formula:

[0116] Geophone point station number = geophone line number × 10000 + geophone point number;

[0117] Preferably, the letters in the detector line number and the detector point number can be removed.

[0118] In some embodiments of the present invention, the first data format is:

[0119] Shot point station number, identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, elevation.

[0120] The identifier is a symbol or letter used to distinguish shot points of different types or attributes. In seismic exploration, different types of shot points may need to be distinguished using different identifiers, such as main shot points, auxiliary shot points, monitoring shot points, etc.

[0121] The well depth refers to the vertical distance from the wellhead to the bottom of the well in seismic exploration. In some exploration projects, geophones may need to be deployed in the well, and the well depth information can help determine the position of the geophones.

[0122] The wellhead time refers to the shot point trigger time recorded in seismic exploration. This time refers to the exact moment when the shot point is triggered at the wellhead and is used for comparison and synchronization with the trigger times of other detector points.

[0123] The charge amount refers to the explosive charge amount used at the shot point in seismic exploration. The size of the explosive charge amount will affect the energy release of the seismic wave and has an important impact on the quality and interpretation of seismic exploration data.

[0124] The X coordinate and Y coordinate of the shot point are used to describe the horizontal position of the shot point on the ground plane. These coordinates can be represented using a geographic coordinate system or other coordinate systems.

[0125] The elevation refers to the ground height of the shot point, usually based on sea level. The elevation information can help determine the vertical position of the shot point.

[0126] In some embodiments of the present invention, the second data format is:

[0127] Detector point station number, identifier, detector point X coordinate, detector point Y coordinate, elevation.

[0128] The identifier is a symbol or letter used to distinguish detector points of different types or attributes. In seismic exploration, different types or arrangement methods of detector points may need to be distinguished using different identifiers, such as main detector points, auxiliary detector points, downhole detector points, etc.

[0129] The X coordinate and Y coordinate of the detector point are used to describe the horizontal position of the detector point on the ground plane. These coordinates can be represented using a geographic coordinate system or other coordinate systems.

[0130] Elevation refers to the ground height of the geophone point, usually referenced to sea level. Elevation information can help determine the vertical position of the geophone point.

[0131] In some embodiments of the present invention, referring to Figure 4 , step 300 includes:

[0132] Step 301: When the identifier of each trace in the original shot point data and the original geophone point data has a first mapping relationship with the shot point station number and the geophone point station number, determine the first calculation parameter of the seismic acquisition system according to the original shot point data and the original geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the shot point station number, and the identifier of each trace in the original geophone point data is the geophone point station number;

[0133] In the original shot point data and the original geophone point data, the following judgment is made. If the identification information of each trace of the original shot point data provided by the acquisition is a 9-digit shot point station number, and the identification information of each trace of the original geophone point data provided by the acquisition is a 9-digit geophone point station number, then directly read the shot point coordinates and other information corresponding to each shot from the original shot point data according to the shot point station number, and read the geophone point coordinates and other information corresponding to each geophone point from the original geophone point data.

[0134] Step 302: Determine the seismic acquisition system according to the first calculation parameter.

[0135] Determine the first calculation parameter according to the shot point coordinates and other information and the geophone point coordinates and other information read in step 301, and load the grid according to the first calculation parameter to calculate information such as trace interval, bin size, fold, offset, shot interval, receiver line interval, shot line interval, etc., so as to determine the seismic acquisition system.

[0136] In some embodiments of the present invention, referring to Figure 5 , step 300 further includes:

[0137] Step 303: When the identifier of each trace in the original shot point data and the original geophone point data has a second mapping relationship with the shot point station number and the geophone point station number, determine the second calculation parameter of the seismic acquisition system according to the transition shot point data and the transition geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the sum of the shot line number and the shot number, and the identifier of each trace in the original geophone point data is the sum of the geophone line number and the geophone point number;

[0138] In the original shot point data and original geophone point data, the following judgments are made. If the identification information of each shot in the collected original shot point data is a 5-digit shot line number and a 4-digit shot point number (the thousands digit is 0, or it may be a 3-digit number), and the identification information of the geophone points in the original geophone point data is a 5-digit geophone line number and a 4-digit geophone point number (the thousands digit is 0, or it may be a 3-digit number), then the information needs to be recalculated to obtain a 9-digit shot point station number and geophone point station number, that is, shot line number × 10000 + shot point number, geophone line number × 10000 + geophone point number. Then, according to the shot point station number, the shot point coordinates, well depth, charge amount, elevation, etc. information corresponding to each shot are read from the transitional shot point data, and the geophone point coordinates, elevation, etc. information corresponding to each geophone point are read from the transitional geophone point data.

[0139] Step 304: Determine the seismic observation system according to the second calculation parameter.

[0140] Based on the shot point coordinates, well depth, charge amount, elevation, etc. information corresponding to each shot in step 303 and the geophone point coordinates, elevation, etc. information corresponding to each geophone point, calculate the second calculation parameter, and load the grid according to the second calculation parameter to calculate information such as trace interval, bin size, fold, offset, shot interval, receiver line interval, shot line interval, etc., so as to determine the seismic observation system.

[0141] As can be seen from the above description, the embodiment of the present invention provides a method for determining a seismic observation system based on a nodal seismograph, including: first, converting the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number; then, converting the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes the geophone point station number; finally, determining the seismic observation system according to the original shot point data, original geophone point data, transitional shot point data, and transitional geophone point data.

[0142] For the data collected by the nodal seismograph, in the case of no relationship file, the present invention can determine the seismic observation system in real time, improving the quality control efficiency and processing efficiency of the collected data. The purpose of the present invention is for land P-wave nodal seismograph acquisition. Based on the characteristics of the data collected by the nodal seismograph, using the information of shot points and geophone points, in the case of no relationship file, quickly define the seismic observation system and perform on-site monitoring and processing of the collected data.

[0143] Embodiment III:

[0144] In a specific implementation manner, the present invention also provides a specific implementation manner of a method for determining a seismic observation system based on a nodal seismograph. Refer to Figure 6 And Figure 7 , which specifically includes the following steps.

[0145] S1: Rearrange the obtained shot point file S to get the S1 file containing information such as the shot point coordinates corresponding to the shot point station number.

[0146] Specifically, rearrange the shot point file S provided by the acquisition. The format of the obtained S file has each column representing the shot line number (the letter S indicates that this file is a shot point file), point number, identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, elevation, and shot time (binary) (see Figure 8 ). Rearrange it into the following format (see Figure 9 ), where each column represents the shot point station number (shot line number × 10000 + shot point number, the letter S is not needed), identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, and elevation.

[0147] S2: Rearrange the obtained geophone point file R to get the R1 file containing information such as the geophone point coordinates corresponding to the geophone point station number.

[0148] Specifically, rearrange the geophone point file R provided by the acquisition. The format of the obtained R file has each column representing the geophone line number (the letter R indicates that this file is a geophone point file), point number, identifier, (five columns of invalid information), geophone point X coordinate, geophone point Y coordinate, and elevation (see Figure 10 ). Rearrange it into the following format (see Figure 11 ), where each column represents the geophone point station number (geophone line number * 10000 + geophone point number, the letter R is not needed), identifier, geophone point X coordinate, geophone point Y coordinate, and elevation.

[0149] S3: Determine the calculation parameters of the seismic acquisition system.

[0150] Check the obtained original data (shot point file S and geophone point file R). If the identification information of each trace in the original data provided by the acquisition is a 9-digit shot point station number and geophone point station number, directly read the information such as the shot point coordinates corresponding to each shot from the S1 file, and read the information such as the geophone point coordinates corresponding to each geophone point from the R1 file.

[0151] If the identification information of each shot in the original data provided by the acquisition is a 5-digit shot line number and a 4-digit shot point number (the thousands digit is 0, or it may also be a 3-digit number), and the geophone point information is a 5-digit geophone line number and a 4-digit geophone point number (the thousands digit is 0, or it may also be a 3-digit number), then it is necessary to recalculate the information in the data to obtain a 9-digit shot point station number and geophone point station number, that is, shot line number × 10000 + shot point number, geophone line number × 10000 + geophone point number. Then, according to the shot point station number, read the information such as the shot point coordinates, well depth, charge amount, elevation, etc. corresponding to each shot from the S1 file, and read the information such as the geophone point coordinates, elevation, etc. corresponding to each geophone point from the R1 file.

[0152] S4: Load the grid according to the calculation parameters of the seismic observation system to determine the seismic observation system.

[0153] Load the grid, calculate information such as offset, that is, determine the seismic observation system. Refer to Figure 12 , which is a single-shot schematic diagram after defining the observation system using this method. The black line in the figure is the offset curve. It can be seen that the offset curve is correct, indicating that the position relationship between the shot point and the receiving point of this single shot is correct. Then, refer to Figure 13 , which is the position map of the shot point and the geophone point of this single shot. The five-pointed star in the figure is the position of the shot point, and the black line area around the five-pointed star is the position of the geophone point. Thus, the number of receiving arrays and channels corresponding to this single shot is correct.

[0154] As can be seen from the above description, the embodiment of the present invention provides a method for determining a seismic observation system based on nodal instruments, including: first, convert the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number; then, convert the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes the geophone point station number; finally, determine the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

[0155] For the data collected by nodal instruments, in the case of no relationship file, the present invention can determine the seismic observation system in real time, improving the quality control efficiency and processing efficiency of the collected data. The purpose of the present invention is to aim at the collection of land P-wave nodal instruments, based on the characteristics of the data collected by nodal instruments, utilize the information of the shot point and the geophone point, and quickly define the seismic observation system in the case of no relationship file to perform on-site monitoring and processing of the collected data.

[0156] The present invention provides a reliable quantitative index to analyze the change trend of the imaging results of different observation systems, solving the problem that the subtle differences in the imaging results cannot be visually distinguished.

[0157] Embodiment 4:

[0158] Based on the same inventive concept, an embodiment of the present application further provides a determining device for a seismic observation system based on a nodal seismograph, which can be used to implement the method described in the above embodiment, as in the following embodiment. Since the principle of the determining device for the seismic observation system based on the nodal seismograph to solve problems is similar to that of the determining method for the seismic observation system based on the nodal seismograph, the implementation of the determining device for the seismic observation system based on the nodal seismograph can refer to the implementation of the determining method for the seismic observation system based on the nodal seismograph, and the repeated parts will not be elaborated. As used hereinafter, the term "unit" or "module" can be a combination of software and / or hardware that can implement a predetermined function. Although the systems 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.

[0159] An embodiment of the present invention provides a specific implementation manner of a determining device for a seismic observation system based on a nodal seismograph that can implement the determining method for the seismic observation system based on the nodal seismograph, see Figure 14 , a determining device for a seismic observation system based on a nodal seismograph includes:

[0160] A shot point data conversion module 10, configured to convert the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes a shot point station number;

[0161] A geophone point data conversion module 20, configured to convert the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes a geophone point station number;

[0162] A seismic observation system determination module 30, configured to determine the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

[0163] In an embodiment of the present invention, a determining device for a seismic observation system based on a nodal seismograph further includes:

[0164] A shot point station number determination module, configured to determine the shot point station number of the transitional shot point data according to the shot line number and the shot point number in the original shot point data.

[0165] In an embodiment of the present invention, a determining device for a seismic observation system based on a nodal seismograph further includes:

[0166] A geophone point station number determination module, configured to determine the geophone point station number of the transitional geophone point data according to the geophone line number and the geophone point number in the original geophone point data.

[0167] In an embodiment of the present invention, the first data format is:

[0168] Shot point station number, identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, elevation.

[0169] In an embodiment of the present invention, the second data format is as follows:

[0170] Geophone point station number, identifier, geophone point X coordinate, geophone point Y coordinate, elevation.

[0171] In an embodiment of the present invention, the seismic observation system determination module includes:

[0172] A first calculation parameter determination unit, configured to determine a first calculation parameter of the seismic observation system according to the original shot point data and the original geophone point data when the identifier of each trace in the original shot point data and the original geophone point data has a first mapping relationship with the shot point station number and the geophone point station number; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the shot point station number, and the identifier of each trace in the original geophone point data is the geophone point station number;

[0173] A first seismic observation system determination unit, configured to determine the seismic observation system according to the first calculation parameter.

[0174] In an embodiment of the present invention, the seismic observation system determination module further includes:

[0175] A second calculation parameter determination unit, configured to determine a second calculation parameter of the seismic observation system according to the transition shot point data and the transition geophone point data when the identifier of each trace in the original shot point data and the original geophone point data has a second mapping relationship with the shot point station number and the geophone point station number; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the sum of the shot line number and the shot point number, and the identifier of each trace in the original geophone point data is the sum of the geophone line number and the geophone point number;

[0176] A second seismic observation system determination unit, configured to determine the seismic observation system according to the second calculation parameter.

[0177] As can be seen from the above description, an embodiment of the present invention provides a determination device for a seismic observation system based on a nodal instrument, including: a shot point data conversion module, configured to convert the pre-acquired original shot point data into transition shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number; a geophone point data conversion module, configured to convert the pre-acquired original geophone point data into transition geophone point data according to a preset second data format; the second data format at least includes the geophone point station number; a seismic observation system determination module, configured to determine the seismic observation system according to the original shot point data, the original geophone point data, the transition shot point data, and the transition geophone point data.

[0178] The determining device of the seismic observation system based on a nodal seismograph provided by an embodiment of the present invention can quickly determine the seismic data observation system in the case of no relationship file for the data collected by the nodal seismograph, and can be applied to the on-site forward monitoring and processing of the data collected by the nodal seismograph. Specifically, the present invention collects the given shot point file and geophone point file, reorganizes them into the format of shot point station numbers and geophone point station numbers, corresponds one by one with the shot point station numbers and geophone point station numbers in the collected data, reads the information such as the coordinates and elevations of the shot points and geophone points required for processing, quickly determines the observation system, and conducts real-time quality control and processing of the collected data to ensure the quality of the collected data and improve the processing efficiency.

[0179] Embodiment 5:

[0180] An embodiment of the present application also provides a specific implementation manner of an electronic device that can implement all the steps in the method for determining the seismic observation system based on a nodal seismograph in the above embodiment. Refer to Figure 15 , and the electronic device specifically includes the following:

[0181] A processor 1201, a memory 1202, a communication interface 1203, and a bus 1204;

[0182] Among them, the processor 1201, the memory 1202, and the communication interface 1203 communicate with each other through the bus 1204; the communication interface 1203 is used to implement information transmission between related devices such as the server-side device and the client-side device;

[0183] The processor 1201 is used to call the computer program in the memory 1202. When the processor executes the computer program, it implements all the steps in the method for determining the seismic observation system based on a nodal seismograph in the above embodiment. For example, when the processor executes the computer program, it implements the following steps:

[0184] Convert the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number;

[0185] Convert the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes the geophone point station number;

[0186] Determine the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

[0187] In one embodiment, a method for determining a seismic observation system based on a nodal seismograph further includes:

[0188] Determine the shot point station number of the transition shot point data according to the shot line number and the shot point number in the original shot point data.

[0189] In one embodiment, a determination method for a seismic observation system based on a nodal seismograph further includes:

[0190] Determine the geophone point station number of the transition geophone point data according to the geophone line number and the geophone point number in the original geophone point data.

[0191] In one embodiment, the first data format is:

[0192] Shot point station number, identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, elevation.

[0193] In one embodiment, the second data format is:

[0194] Geophone point station number, identifier, geophone point X coordinate, geophone point Y coordinate, elevation.

[0195] In one embodiment, determining the seismic observation system according to the original shot point data, the original geophone point data, the transition shot point data, and the transition geophone point data includes:

[0196] When the identifier of each trace in the original shot point data and the original geophone point data has a first mapping relationship with the shot point station number and the geophone point station number, determine the first calculation parameter of the seismic observation system according to the original shot point data and the original geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the shot point station number, and the identifier of each trace in the original geophone point data is the geophone point station number;

[0197] Determine the seismic observation system according to the first calculation parameter.

[0198] In one embodiment, determining the seismic observation system according to the original shot point data, the original geophone point data, the transition shot point data, and the transition geophone point data further includes:

[0199] When the identifier of each trace in the original shot point data and the original geophone point data has a second mapping relationship with the shot point station number and the geophone point station number, determine the second calculation parameter of the seismic observation system according to the transition shot point data and the transition geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the sum of the shot line number and the shot point number, and the identifier of each trace in the original geophone point data is the sum of the geophone line number and the geophone point number;

[0200] Determine the seismic observation system according to the second calculation parameter.

[0201] Embodiment Six:

[0202] An embodiment of the present application also provides a computer-readable storage medium capable of implementing all steps in the method for determining a seismic observation system based on node instruments in the above embodiments. A computer program is stored on the computer-readable storage medium. When the computer program is executed by a processor, all steps in the method for determining a seismic observation system based on node instruments in the above embodiments are implemented. For example, when the processor executes the computer program, the following steps are implemented:

[0203] Convert the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes the shot point station number;

[0204] Convert the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes the geophone point station number;

[0205] Determine the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

[0206] Each embodiment in this specification is described in a progressive manner. The same or similar parts among the embodiments can be referred to each other, and the differences between each embodiment and other embodiments are emphasized. In particular, for the hardware + program type embodiments, since they are basically similar to the method embodiments, the description is relatively simple, and the relevant parts can be referred to the partial description of the method embodiments.

[0207] The above describes 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 can be performed in a different order than in the embodiments and still achieve the desired result. Additionally, the processes depicted in the figures do not necessarily require the particular order or sequential order shown to achieve the desired result. In certain embodiments, multitasking and parallel processing are also possible or may be advantageous.

[0208] Although the present application provides method operation steps such as in the embodiments or flowcharts, based on routine or non-creative labor, there can be more or fewer operation steps. The step order listed in the embodiments is only one way among the execution orders of numerous steps and does not represent the only execution order. When the actual device or client product is executed, it can be executed in the order shown in the embodiments or the figures or in parallel (such as in an environment of parallel processors or multithreaded processing).

[0209] For the convenience of description, when describing the above device, various modules are described separately according to their functions. Of course, when implementing the embodiments of this specification, the functions of each module can be implemented in the same or multiple software and / or hardware, or the modules that implement the same function can be realized by a combination of multiple sub-modules or sub-units. The device embodiments described above are merely illustrative. For example, the division of the units is only a logical function division, and there may be other division methods in actual implementation. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the displayed or discussed couplings or direct couplings or communication connections to each other can be through some interfaces, and the indirect couplings or communication connections of the devices or units can be in electrical, mechanical or other forms.

[0210] Those skilled in the art also know that in addition to implementing the controller in the form of pure computer-readable program code, the method steps can be logically programmed to enable the controller to be implemented in the form of logic gates, switches, application-specific integrated circuits, programmable logic controllers, embedded microcontrollers, etc. to achieve the same function. Therefore, such a controller can be regarded as a hardware component, and the devices included therein for implementing various functions can also be regarded as the structures within the hardware component. Or even, the devices for implementing various functions can be regarded as either software modules for implementing the method or structures within the hardware component.

[0211] In a typical configuration, a computing device includes one or more processors (CPUs), an input / output interface, a network interface, and memory.

[0212] The memory may include non-permanent memory in the form of computer-readable media, random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash memory (flash RAM). The memory is an example of computer-readable media.

[0213] The various embodiments in this specification are described in a progressive manner. For the same or similar parts among the embodiments, reference can be made to each other, and the key point of each embodiment is to illustrate the differences from other embodiments. In particular, for the system embodiment, since it is basically similar to the method embodiment, the description is relatively simple, and for the relevant parts, reference can be made to the description of the method embodiment. In the description of this specification, the description with reference to terms such as "one embodiment", "some embodiments", "example", "specific example", or "some examples" means that the specific features, structures, materials, or characteristics described in connection with the embodiment or example are included in at least one embodiment or example of the embodiments in this specification. In this specification, the schematic expressions of the above terms do not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials, or characteristics described can be combined in a suitable manner in any one or more embodiments or examples. In addition, without contradiction, those skilled in the art can combine and combine the different embodiments or examples described in this specification and the features of different embodiments or examples.

[0214] The above are only the embodiments of the embodiments in this specification and are not used to limit the embodiments in this specification. For those skilled in the art, various changes and modifications can be made to the embodiments in this specification. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principle of the embodiments in this specification shall be included within the scope of the claims of the embodiments in this specification.

Claims

1. A method for determining a seismic observation system based on a node instrument, characterized in that, comprising: Converting the pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes a shot point station number; Converting the pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes a geophone point station number; Determining the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

2. The method for determining a seismic observation system according to claim 1, characterized in that, further comprising: Determining the shot point station number of the transitional shot point data according to the shot line number and the shot point number in the original shot point data.

3. The method for determining a seismic observation system according to claim 1, characterized in that, further comprising: Determining the geophone point station number of the transitional geophone point data according to the geophone line number and the geophone point number in the original geophone point data.

4. The method for determining a seismic observation system according to claim 1, characterized in that, The first data format is: Shot point station number, identifier, well depth, wellhead time, charge amount, shot point X coordinate, shot point Y coordinate, elevation.

5. The method for determining a seismic observation system according to claim 1, characterized in that, The second data format is: Geophone point station number, identifier, geophone point X coordinate, geophone point Y coordinate, elevation.

6. The method for determining a seismic observation system according to any one of claims 1 to 5, characterized in that, Determining the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data, comprising: When the identifier of each trace in the original shot point data and the original geophone point data has a first mapping relationship with the shot point station number and the geophone point station number, determining the first calculation parameter of the seismic observation system according to the original shot point data and the original geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the shot point station number, and the identifier of each trace in the original geophone point data is the geophone point station number; Determining the seismic observation system according to the first calculation parameter.

7. The method for determining a seismic observation system according to claim 6, characterized in that, Determining the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data, further comprising: When the identifier of each trace in the original shot point data and the original geophone point data has a second mapping relationship with the shot point station number and the geophone point station number, determining the second calculation parameter of the seismic observation system according to the transitional shot point data and the transitional geophone point data; wherein, the first mapping relationship is that the identifier of each trace in the original shot point data is the sum of the shot line number and the shot point number, and the identifier of each trace in the original geophone point data is the sum of the geophone line number and the geophone point number; Determining the seismic observation system according to the second calculation parameter.

8. An apparatus for determining a seismic observation system based on a nodal seismograph, characterized in that, comprising: a shot point data conversion module, configured to convert pre-acquired original shot point data into transitional shot point data according to a preset first data format; wherein, the first data format at least includes a shot point station number; a geophone point data conversion module, configured to convert pre-acquired original geophone point data into transitional geophone point data according to a preset second data format; the second data format at least includes a geophone point station number; a seismic observation system determination module, configured to determine the seismic observation system according to the original shot point data, the original geophone point data, the transitional shot point data, and the transitional geophone point data.

9. An electronic device, comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, when the processor executes the program, the steps of a method for determining a seismic observation system based on a nodal seismograph according to any one of claims 1 to 7 are implemented.

10. A computer-readable storage medium, on which a computer program is stored, characterized in that, when the computer program is executed by a processor, the steps of a method for determining a seismic observation system based on a nodal seismograph according to any one of claims 1 to 7 are implemented.

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