Shotpoint placement method and apparatus
By using a well-seismic fusion method for shot placement, the problems of high well-shot construction costs and poor source data quality have been solved, enabling efficient and economical high-resolution seismic exploration, improving the frequency and signal-to-noise ratio of seismic data, and expanding the exploration market.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- CHINA NAT PETROLEUM CORP
- Filing Date
- 2024-12-09
- Publication Date
- 2026-06-09
AI Technical Summary
In seismic exploration, existing technologies such as well-shot seismic drilling are costly and difficult to implement, while source seismic drilling provides poor data quality, making it difficult to simultaneously meet the requirements of high resolution and efficient acquisition.
By adopting a well-seismic fusion shot point layout method, which combines the advantages of well-shot excitation and source excitation, and by determining the design well-seismic ratio and shot-row spacing, well-shot and source shot points are deployed to improve the frequency and resolution of seismic data while reducing exploration costs.
While controlling costs, the frequency and resolution of seismic data were improved, especially in special terrains such as the Changling fault depression, which enhanced the signal-to-noise ratio of high-frequency signals, broadened the bandwidth, and promoted the expansion of the oil and gas discovery and exploration market.
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Figure CN122172268A_ABST
Abstract
Description
Technical Field
[0001] This application relates to the fields of geophysical exploration and acquisition technology and exploration and acquisition design technology, and in particular to a shot point layout method and device, as well as a seismic data acquisition method and electronic equipment based on well-seismic fusion shot point design. Background Technology
[0002] Currently, in the design of seismic exploration and observation systems, it is common to consider either all shot points as well-shot or all source points. When implementing the design, if well-shot firing technology is used, source-filling technology is employed in areas where well-shot firing is inaccessible, such as towns, environmental protection zones, and high-speed rail lines. If source-firing technology is used, well-shot firing technology is employed in mountainous areas and waterways inaccessible to seismic source vehicles. However, while the all-well-shot approach offers the advantage of high-quality seismic data, it suffers from difficulties in implementation, high exploration costs, and challenges in achieving efficient data acquisition. While the all-source approach is relatively cheaper than the all-well-shot approach, the data quality is poor, with low resolution, often failing to meet acquisition requirements. Therefore, to meet the high-resolution requirements of geological tasks, there is an urgent need for a shot point deployment method that can combine the advantages of both well-shot firing and source-firing, integrating them to simultaneously meet the requirements of data quality and acquisition efficiency. Summary of the Invention
[0003] This application provides a shot point layout method and device, as well as a seismic data acquisition method and electronic equipment based on well-seismic fusion shot point design, which can combine the advantages of well-shot excitation and source excitation, and fuse well-shot excitation and source excitation to simultaneously meet the requirements of data quality and acquisition construction efficiency.
[0004] In a first aspect, this application provides a method for shot point deployment, which includes: acquiring acquisition task information and observation system parameters, wherein the acquisition task information includes frequency information required by the task, and the observation system parameters include source shot point density; wherein the observation system parameters are parameters used when performing the acquisition task in a source construction manner; acquiring the design well-to-seismic ratio; wherein the seismic data obtained by construction with the design well-to-seismic ratio meets the requirements of the frequency information; determining the shot row spacing, shot point location, number of well-to-shot shot point rows to be deployed, and number of source-to-shot shot point rows based on the source shot point density and the design well-to-shot ratio; and deploying the well-to-shot shot points and the source-to-shot shot points based on the shot row spacing, the shot point location, the number of well-to-shot shot point rows, and the number of source-to-shot shot point rows.
[0005] As an optional implementation, the method further includes: acquiring multiple different preset well-seismic ratios; for each preset well-seismic ratio, determining the shot spacing, shot location, number of well-shot shot rows, and number of source-shot shot rows based on the source shot density and the preset well-seismic ratio; obtaining seismic data corresponding to different preset well-seismic ratios through simulation calculation based on the shot spacing, shot location, number of well-shot shot rows, and number of source-shot shot rows; and using the preset well-seismic ratios whose seismic data meet the requirements of the frequency information as the design well-seismic ratio.
[0006] As an optional implementation, the roughness calculation based on the elevation value includes using a preset well-to-seismic ratio that meets the frequency information requirements of the seismic data as the design well-to-seismic ratio, which includes: determining the highest frequency that the acquisition task needs to achieve based on the frequency information required by the task; and using the preset well-to-seismic ratio corresponding to the seismic data to which the stacked profile belongs as the design well-to-seismic ratio when there is a continuous effective signal that can reach the highest frequency in the stacked profile.
[0007] As an optional implementation, the blast row spacing includes the blast row spacing of the well blast points and the blast row spacing of the seismic source blast points. The step of determining the blast row spacing, blast point locations, the number of well blast point rows to be deployed, and the number of seismic source blast point rows based on the seismic source blast point density and the designed well-to-seismic ratio includes: determining the blast row spacing of the seismic source blast points based on the seismic source blast point density; determining the well blast point density based on the designed well-to-seismic ratio and the seismic source blast point density; determining the blast row spacing of the well blast points based on the well blast point density; and determining the blast point locations, the number of well blast point rows to be deployed, and the number of seismic source blast point rows based on the blast row spacing, the seismic source blast point density, and the well blast point density.
[0008] As an optional implementation, the ratio of the well shot density to the seismic source shot density is rounded to equal the well-seismic ratio.
[0009] Secondly, this application provides a shot point deployment device, comprising: a first module for acquiring acquisition task information and observation system parameters, wherein the acquisition task information includes frequency information required by the task, and the observation system parameters include source shot point density; wherein the observation system parameters are parameters used when performing the acquisition task in a source construction manner; a second module for acquiring the design well-to-seismic ratio; wherein the seismic data obtained by construction with the design well-to-seismic ratio meets the requirements of the frequency information; a third module for determining the shot row spacing, shot point location, number of well shot point rows to be deployed, and number of source shot point rows based on the source shot point density and the design well-to-seismic ratio; and a fourth module for deploying the well shot points and the source shot points based on the shot row spacing, the shot point location, the number of well shot point rows, and the number of source shot point rows.
[0010] Thirdly, this application provides a seismic data acquisition method based on well-seismic fusion shot point design, comprising: determining the well-seismic ratio; using the well-seismic ratio as the design well-seismic ratio, applying the above-mentioned shot point layout method to deploy well-shot and source shot points for performing the acquisition task; and performing excitation based on the well-shot and source shot points to obtain seismic data that meets the frequency information requirements.
[0011] As an optional implementation, determining the well-seismic ratio includes: acquiring multiple different preset well-seismic ratios; for each preset well-seismic ratio, determining the shot row spacing, shot point location, number of well shot row positions, and number of source shot row positions based on the total number of shot points and the preset well-seismic ratio; obtaining seismic data corresponding to different preset well-seismic ratios through simulation calculation based on the shot row spacing, shot point location, number of well shot row positions, and number of source shot row positions; and using the preset well-seismic ratios whose seismic data meet the requirements of the frequency information as the design well-seismic ratio.
[0012] Fourthly, this application provides an electronic device, including a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; the memory is used to store computer programs; and the processor is used to execute the program stored in the memory to implement the above-mentioned shot point layout method or the seismic data acquisition method based on well-seismic fusion shot point design.
[0013] The technical solutions provided in this application have the following advantages compared with the prior art:
[0014] The shot placement method provided in this application combines the advantages of well shot and seismic source, employing a well-seismic fusion shot placement method. This method increases the frequency of raw data while controlling costs, utilizing the high resolution of well shot data and the high efficiency of seismic source construction, thus improving economic efficiency. By optimizing the well-seismic ratio, it achieves high-efficiency exploration, increasing the frequency of raw data from the seismic source excitation technology in the Central Depression by approximately 15Hz, meeting the needs of efficient exploration. While improving data resolution, it reduces exploration costs, especially when applied to special terrains such as the Changling fault depression. By designing a suitable well-seismic ratio, it effectively improves the signal-to-noise ratio of high-frequency signals in the Changling fault depression, further broadening the bandwidth of the raw data acquisition, thereby promoting oil and gas discovery and expanding the exploration market. It has broad application prospects and market potential. Attached Figure Description
[0015] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.
[0016] To more clearly illustrate the technical solutions in the embodiments of this application or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, for those skilled in the art, other drawings can be obtained based on these drawings without creative effort.
[0017] Figure 1 This schematically illustrates the system architecture of the blast point layout method and apparatus applicable to embodiments of this application;
[0018] Figure 2 This is a flowchart illustrating a method for setting up firing points according to an embodiment of this application;
[0019] Figure 3 A flowchart illustrating a method for setting up firing points according to another embodiment of this application;
[0020] Figure 4(a) is one of the schematic diagrams of the firing point layout method according to an embodiment of the present application;
[0021] Figure 4(b) is a second schematic diagram of the firing point layout method according to an embodiment of the present application;
[0022] Figure 4(c) is a third schematic diagram of the firing point layout method according to an embodiment of the present application;
[0023] Figure 4(d) is a fourth schematic diagram of the firing point layout method according to an embodiment of this application;
[0024] Figure 5 This is one of the superimposed cross-sectional schematic diagrams according to another embodiment of this application;
[0025] Figure 6 This is a second superimposed cross-sectional schematic diagram according to another embodiment of this application;
[0026] Figure 7 This is a third superimposed cross-sectional schematic diagram according to another embodiment of this application;
[0027] Figure 8 This is the fourth superimposed cross-sectional schematic diagram according to another embodiment of this application;
[0028] Figure 9 This is the fourth superimposed cross-sectional schematic diagram according to another embodiment of this application;
[0029] Figure 10 This is the fourth superimposed cross-sectional schematic diagram according to another embodiment of this application;
[0030] Figure 11 This is a schematic diagram of the structure of an electronic device according to an embodiment of this application. Detailed Implementation
[0031] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this application, not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.
[0032] In the design of seismic exploration observation systems and the layout of shot points, the surface geological conditions of different exploration tasks vary greatly, especially in some basin areas. Due to their inherent geological characteristics, such as central depressions, high-resolution exploration presents significant challenges. Both whole-well shot and whole-source construction schemes have considerable limitations, failing to guarantee both seismic data quality and construction efficiency. Furthermore, no practical demonstration of a fusion scheme has been conducted. Therefore, based on actual working conditions, this application proposes a shot point design method for well-seismic fusion to solve the problem of high-resolution exploration in specific areas. It utilizes the high resolution of well shot data and the high efficiency of source construction to achieve high-efficiency exploration, improving data resolution while reducing exploration costs and meeting the needs of efficient exploration.
[0033] Figure 1 This schematically illustrates the system architecture of the blast point layout method and apparatus applicable to embodiments of this application;
[0034] Reference Figure 1 As shown, the system architecture 100 of the sniping point deployment method and apparatus applicable to embodiments of this application includes: terminal devices 101, 102, and 103, a network 104, and a server 105. The network 104 serves as a medium for providing a communication link between the terminal devices 101, 102, and 103 and the server 105. The network 104 may include various connection types, such as wired or wireless communication links, or fiber optic cables, etc.
[0035] Users can use terminal devices 101, 102, and 103 to interact with server 105 via network 104 to receive or send messages, etc. Terminal devices 101, 102, and 103 can have audio / video capture devices, image / audio / video playback applications, etc., installed. Other communication client applications can also be installed, such as web browser applications, search applications, image storage and processing applications, instant messaging tools, email clients, and social media platform software (for example only).
[0036] Terminal devices 101, 102, and 103 can be various electronic devices with displays and supporting software that can implement the shot placement method. These electronic devices include, but are not limited to, smartphones, tablets, laptops, desktop computers, etc.
[0037] Server 105 can be a server that provides various services, such as a back-end management server that provides support for data processing of work area data received and stored by users using terminal devices 101, 102, and 103 (this is just an example). The back-end management server can analyze and process the received data and feed back the processing results (such as web pages, information, or data obtained or generated according to user requests) to the terminal devices.
[0038] It should be noted that the firing point deployment method provided in this application embodiment can generally be executed by server 105 or a terminal device with a certain computing power. Correspondingly, the firing point deployment device provided in this application embodiment can generally be installed in server 105 or the aforementioned terminal device with a certain computing power. The firing point deployment method provided in this application embodiment can also be executed by a server or server cluster that is different from server 105 and capable of communicating with terminal devices 101, 102, 103 and / or server 105. Correspondingly, the firing point deployment device provided in this application embodiment can also be installed in a server or server cluster that is different from server 105 and capable of communicating with terminal devices 101, 102, 103 and / or server 105.
[0039] It should be understood that Figure 1 The number of terminal devices, networks, and servers shown is merely illustrative. Depending on implementation needs, any number of terminal devices, networks, and servers can be included.
[0040] Figure 2 This is a flowchart illustrating a method for setting up firing points according to an embodiment of this application; as shown... Figure 2 As shown in the figure, this application provides a method for setting up firing points, which includes the following steps:
[0041] S1, acquire acquisition task information and observation system parameters. The acquisition task information includes the frequency information required by the task, and the observation system parameters include the source shot density. The observation system parameters are the parameters used when the acquisition task is performed in the manner of source construction.
[0042] S2, obtain the design well seismic ratio; wherein the seismic data obtained by construction based on the design well seismic ratio meets the requirements of the frequency information;
[0043] S3. Based on the source shot density and the designed well-seismic ratio, determine the shot row spacing, shot location, number of well shot rows to be deployed, and number of source shot rows.
[0044] S4. Based on the blast row spacing, the blast point location, the number of blast point rows in the well and the number of seismic source blast point rows, the well blast point and the seismic source blast point are deployed.
[0045] Specifically, in S1, during seismic exploration, the acquisition task typically includes requirements for the required seismic data, such as frequency information requirements, which may be the frequency requirements of the target layer. The observation system parameters may be the parameters of the observation system designed according to the two-width-one-height seismic acquisition method for source construction, and the parameters when the acquisition task is executed in the source construction mode, that is, the observation system parameters determined assuming the full source scheme is used for acquisition.
[0046] Specifically, in S2, the design well-seismic ratio can be determined according to the following operations: acquiring multiple different preset well-seismic ratios; for each preset well-seismic ratio, determining the shot spacing, shot location, number of well-shot shot rows, and number of source-shot shot rows based on the source shot density and the preset well-seismic ratio; obtaining seismic data corresponding to different preset well-seismic ratios through simulation calculation based on the shot spacing, shot location, number of well-shot shot rows, and number of source-shot shot rows; and using the preset well-seismic ratios whose seismic data meet the requirements of the frequency information as the design well-seismic ratio.
[0047] The operation of using the preset well-to-seismic ratio of the seismic data that meets the frequency information requirements as the design well-to-seismic ratio may include: determining the highest frequency that the acquisition task needs to achieve based on the frequency information required by the task; and using the preset well-to-seismic ratio corresponding to the seismic data of the stacked profile as the design well-to-seismic ratio when there is a continuous effective signal in the stacked profile that can reach the highest frequency.
[0048] In one possible implementation, if there are multiple preset well-seismic ratios that meet the requirements of the frequency information, then the minimum preset well-seismic ratio among the multiple preset well-seismic ratios is taken as the design well-seismic ratio.
[0049] For example, when comparing and selecting seismic data based on multiple preset well-seismic ratios, the minimum preset well-seismic ratio among the well-seismic ratios is selected as the design well-seismic ratio based on the above operation. That is, the scheme with the lowest percentage of well shot points. Since well shot costs are relatively higher, this can further reduce costs and improve the economics of exploration projects.
[0050] Specifically, the blast row spacing includes the blast row spacing of the well blast points and the blast row spacing of the seismic source blast points. S3 can be implemented by including the following operations: determining the blast row spacing of the seismic source blast points based on the density of the seismic source blast points; determining the density of the well blast points based on the designed well-seismic ratio and the density of the seismic source blast points; determining the blast row spacing of the well blast points based on the density of the well blast points; and determining the blast point location, the number of well blast point rows to be deployed, and the number of seismic source blast point rows based on the blast row spacing, the density of the seismic source blast points, and the density of the well blast points.
[0051] For example, based on the acquisition task information and observation system parameters obtained in S1, the parameters for executing the acquisition task using the source construction method can be obtained. That is, the source shot density under full-source excitation is determined, specifying how many source shot points per square kilometer. This shot point density satisfies the acquisition requirements of two widths and one height. According to the geological requirements in the acquisition task information, the highest frequency that the seismic acquisition task needs to achieve is determined. The frequency that the designed well-to-seismic ratio can meet this requirement is determined. That is, the number of well-to-seismic shot points per square kilometer determined by the designed well-to-seismic ratio, i.e., the well-to-seismic shot point density, can ensure that the seismic data meets the vertical frequency requirements.
[0052] In one possible implementation, the ratio of the density of well shot points to the density of seismic source shot points is rounded to the nearest integer and equal to the well-to-seismic ratio. For example, the optimal well-to-seismic ratio is obtained by dividing the density of well shot points by the density of seismic source shot points and rounding the result to the nearest integer. This well-to-seismic ratio can also be used in S4 for the deployment of shot points, with the ratio of the number of rows of well shot points to the number of rows of seismic source shot points consistent with this well-to-seismic ratio. Therefore, in subsequent deployment work, it is necessary to arrange well shot points or seismic source shot points at each shot point location. According to the ratio of the number of shot rows, for example, the optimal well-to-seismic ratio is 1:3, when designing the locations, it can be required that one row of shot points consists entirely of well shot points, and correspondingly, three rows of shot points consist entirely of seismic sources.
[0053] As can be seen, this implementation scheme can improve data resolution while reducing exploration costs. In particular, using the minimum preset well-seismic ratio among multiple preset well-seismic ratios as the design well-seismic ratio can minimize costs.
[0054] Based on the above steps, the shot point layout method provided in this application combines the advantages of well shot and seismic source, adopting a well-seismic fusion shot point layout method. While controlling costs, it increases the frequency of raw data, utilizes the high resolution of well shot data and the high efficiency of seismic source construction, and improves economic efficiency. By optimizing the well-seismic ratio, it achieves high-efficiency exploration, increasing the frequency of raw data constructed by the seismic source excitation technology in the central depression by about 15Hz, which can meet the needs of efficient exploration. While improving data resolution, it reduces exploration costs. Especially when applied to special terrains, such as the Changling fault depression area, by designing a suitable well-seismic ratio, it effectively improves the signal-to-noise ratio of high-frequency signals in the Changling fault depression area, further broadens the bandwidth of raw data acquisition, and thus helps promote oil and gas discovery and expand the exploration market. It has broad application prospects and market potential.
[0055] Based on the same inventive concept, this application also provides a seismic data acquisition method based on well-seismic fusion shot point design, which applies the shot point layout method provided in this application. The seismic data acquisition method includes: determining the well-seismic ratio; using the well-seismic ratio as the design well-seismic ratio, applying the above-mentioned shot point layout method to deploy well-shot and source shot points for performing the acquisition task; and exciting based on the well-shot and source shot points to obtain seismic data that meets the frequency information requirements.
[0056] As an optional implementation, determining the well-seismic ratio includes: acquiring multiple different preset well-seismic ratios; for each preset well-seismic ratio, determining the shot row spacing, shot point location, number of well shot row positions, and number of source shot row positions based on the total number of shot points and the preset well-seismic ratio; obtaining seismic data corresponding to different preset well-seismic ratios through simulation calculation based on the shot row spacing, shot point location, number of well shot row positions, and number of source shot row positions; and using the preset well-seismic ratios whose seismic data meet the requirements of the frequency information as the design well-seismic ratio.
[0057] More details and beneficial effects of this embodiment can be found in the descriptions of the foregoing embodiments, and will not be repeated here.
[0058] Figure 3 According to a flowchart illustrating a method for setting up firing points according to another embodiment of this application, combined with... Figure 3 The following example illustrates a three-dimensional seismic exploration project in the Changling fault depression area of the southern central depression of the Songliao Basin. According to an embodiment of this application, the shot point layout method may specifically include the following steps:
[0059] In step 101, the observation system parameters for the source construction were designed according to the two-width-one-height seismic acquisition method.
[0060] In step 102, the shot point density of the seismic source is calculated based on the parameters of the designed observation system, which is how many shot points per square kilometer. This shot point density meets the acquisition requirements of two widths and one height.
[0061] In the parallel 103 steps, the highest frequency that the seismic acquisition task needs to achieve is determined based on geological requirements;
[0062] Step 104 is to design the minimum density of well shot points, which is also how many well shot points per square kilometer. This shot point density only needs to meet the requirements of the longitudinal frequency.
[0063] In step 105, the well shot density in step 104 is divided by the source shot density in step 102.
[0064] The optimal well-vibration ratio in step 106 is the integer ratio of the above values.
[0065] When designing the source points in step 107, the ratio of the number of shot rows should be calculated. For example, the optimal well-to-seismic ratio is 1:5. When designing the points, it is required that all shot points in row 1 are well shots and all shot points in row 5 are seismic sources. This process is repeated to improve data resolution while reducing exploration costs.
[0066] More details and beneficial effects of this embodiment can be found in the descriptions of the foregoing embodiments, and will not be repeated here.
[0067] In another example, the process of determining the well-to-seismic ratio described above can be implemented using various schemes as shown in Table 1 below. The well-to-seismic ratio and parameters for each scheme are as follows: Scheme 1 indicates that all shot points are well-shot points; Scheme 2 indicates that the ratio of well-shot points to seismic source shot points is 1:3; Scheme 3 indicates that the ratio of well-shot points to seismic source shot points is 1:7; Scheme 4 indicates that the ratio of well-shot points to seismic source shot points is 1:9; and the seismic source scheme indicates that all shot points are seismic source shot points.
[0068] Table 1
[0069] Types of solutions Distance between the epicenter and the shot line Well gun firing line distance Remark Well-shot 160m Full well blast Option 1 80m 320m Jing Zhen 1:3 Option 2 80m 480m Jing Zhen 1:5 Option 3 80m 640m Jing Zhen 1:7 Option 4 80m 800m Jing Zhen 1:9 earthquake source 80m Whole source
[0070] Referring to Figure 4, Figures 4(a), 4(b), 4(c), and 4(d) respectively show schematic diagrams of well-seismic locations for schemes 1 to 4. In these diagrams, gray circular icons represent seismic source locations, and rectangular frame icons represent well-shot locations.
[0071] In this example, we take the 3D seismic exploration project in the Changling fault depression area of the central depression in the southern Songliao Basin as an example. The geological conditions of this area include: the current frequency band of the first 3D seismic data in the Changling fault depression of the central depression in the southern Songliao Basin is relatively narrow, with an effective bandwidth of 12-60Hz and a minimum stratum thickness that can be resolved to be 14-20m. This can basically meet the needs of sandstone group-level sandstone prediction, but cannot meet the needs of single sand layer (4-6m) resolution. The reservoir identification accuracy is difficult to meet the geological requirements.
[0072] Based on historical construction records, the well-blasting induction technology employs a single-well, wired single-point, and high-coverage (400 times) construction method, resulting in high signal-to-noise ratio data. Figure 10 As shown, the single-shot scanning frequency of the target layer T2 (burial depth 2200m) is above 70Hz, which is beneficial for distinguishing thin sand layers, but it is difficult to meet the requirements of efficient acquisition, resulting in high exploration costs and failing to meet the requirements of cost-effective exploration. The source-excitation technology adopts a single-source, single-node, and high-coverage (782 / 1564 times) construction method, resulting in abundant low-frequency data. However, the single-shot scanning frequency of the target layer T2 (burial depth 2200m) can only reach 40Hz in the field acquisition. Figure 6As shown, the excitation energy of a single seismic source is weak, the high-frequency signal energy is insufficient, the high-frequency signal is relatively weak, the longitudinal identification capability of earthquakes is limited, and it is not conducive to the differentiation of thin sand bodies.
[0073] Based on the advantages, disadvantages, and limitations of well-shot and source-source seismic operations in the Changling fault depression area, it is understandable that well-shot seismic data has a high dominant frequency and wide bandwidth, strong thin interbedded layer resolution, high acquisition density, and strong ability to identify microstructures and small faults; the wide azimuth data volume meets the requirements for OVT processing and fracture prediction. However, it has high exploration costs, high excitation safety risks, does not meet environmental protection requirements, and is difficult to achieve efficient acquisition. Source-source seismic data has abundant low-frequency information, a wide bandwidth, strong thin sand layer resolution, and high reservoir prediction accuracy; it has high spatial acquisition density, strong ability to identify microstructures and small faults; the wide azimuth data volume meets the requirements for OVT processing and fracture prediction. However, the high-frequency signal energy is insufficient, resulting in limited longitudinal seismic identification capability and inability to identify 4-6 meter thin sand layers.
[0074] Comparing well-shot excitation (BSEE) and source-excitation (MEI) techniques, the receiving factors for 3D seismic data from both techniques are consistent, but the excitation methods and coverage times differ. Based on historical high-frequency seismic data of the target layer, firstly, both techniques utilize a single-point low-frequency 5Hz geophone, ensuring consistent reception. Secondly, the coverage times of the target layer in MEI can be 4, 3, or 2 times the seismic data frequency of well-shot excitation, where the coverage times can be understood as the number of shot points; for example, well-shot coverage times represent the number of shot points set and their proportion. Regardless of the increase in the coverage times, the high-frequency information in the 3D seismic data obtained by MEI is significantly lower than that obtained by well-shot excitation. Therefore, increasing the coverage times cannot solve the problem of high-frequency loss in the source-excitation scheme. Thus, the main factor affecting high frequencies in seismic data is the excitation method. Well-shot excitation can improve the signal-to-noise ratio of high-frequency signals, thereby effectively improving data resolution by increasing the well-to-seismic ratio.
[0075] The above-mentioned schemes with different well-to-seismic ratios include four ratios for integrating well shot points and seismic source shot points, with well-to-seismic ratios of 1:3, 1:5, 1:7, and 1:9. These four schemes are compared and analyzed with construction data based on historical records of well shot activation technology and seismic source activation technology construction.
[0076] Combination Figure 5-10 After simulation calculations of the above four schemes, the seismic data corresponding to the above schemes (different preset well-seismic ratios) were obtained. The superimposed profile of the acquired seismic wave signals is shown in the figure. Figure 5 This is one of the superimposed cross-sectional schematic diagrams according to another embodiment of this application; wherein the superimposed cross-sections of the above-described different schemes across the entire frequency range are shown; Figure 6 This is a second superimposed cross-sectional schematic diagram according to another embodiment of this application; it shows the superimposed cross-section of the above different schemes in the frequency range (40, 50) Hz; Figure 7 This is a third superimposed cross-sectional schematic diagram according to another embodiment of this application; it shows the superimposed cross-section of the above different schemes in the frequency range (45, 55) Hz; Figure 8 This is the fourth superimposed cross-sectional schematic diagram according to another embodiment of this application; it shows the superimposed cross-section of the above different schemes in the frequency range (50, 60) Hz; Figure 9 This is the fourth superimposed cross-sectional schematic diagram according to another embodiment of this application, which shows the superimposed cross-section of the above different schemes in the frequency range (55, 65) Hz; Figure 10 This is the fourth superimposed cross-sectional schematic diagram according to another embodiment of this application, which shows the superimposed cross-sections of the above-described different schemes in the frequency range (60, 70) Hz. In the figure, T1 and T2 are the target layers, with T1 buried at a depth of 1700m and T2 buried at a depth of 2200m.
[0077] From a full-frequency perspective, the data quality is not significantly different. The target layers shown in the figure exhibit good continuity in T1 and T2, with a high signal-to-noise ratio. On the HP(40-50) Hz stacked profile, strong and continuous reflection signals are visible in T1 for both the full-well shot scheme and all four schemes, with good continuity in T2 reflection signals. However, the T2 reflection signal is very weak for the full-source scheme. On the HP(45-55) Hz stacked profile, continuous reflection signals are visible in T1 for all schemes, but no effective reflection signal is visible in T2 for the full-source scheme. On the HP(50-60) Hz stacked profile, the T1 reflection signal is relatively weak for the full-source scheme, while the T2 reflection signals for schemes 3 and 4 are weak. The signal is weak. From the HP(55-65)Hz stacked profile, the T1 reflection signal of the full source scheme is very weak, the T2 reflection signal of scheme 2 is weak, and no effective reflection is seen in the T2 of schemes 3 and 4. From the HP(60-70)Hz stacked profile, no reflection signal is seen in the T1 of the full source scheme, and the T2 reflection signal of the full well shot scheme is weak. From the HP(65-75)Hz stacked profile, the T1 reflection signal of the full well shot scheme and scheme 1 is relatively weak, and no effective reflection signal is seen in the others.
[0078] By deploying a well-seismic fusion observation system, the frequency of the target layer can be effectively improved. When the well-seismic ratio is 1:3, the data quality is basically equivalent to that of the all-well shot scheme, with the T1 scan frequency of the stacked profile reaching 70Hz and the T2 scan frequency reaching 65Hz. When the well-seismic ratio is 1:5, the T1 scan frequency of the stacked profile reaches 65Hz and the T2 scan frequency reaches 60Hz. When the well-seismic ratio is 1:7 and 1:9, the T1 scan frequency of the stacked profile reaches 65Hz and the T2 scan frequency reaches 55Hz. For the all-source scheme, the T1 scan frequency of the stacked profile reaches 55Hz and the T2 scan frequency reaches 45Hz.
[0079] Taking into account the frequency requirements of the target layer, selecting an appropriate well-seismic ratio can improve data resolution while reducing exploration costs, which has a significant impact on promoting oil and gas discoveries and expanding the exploration market.
[0080] The shot placement method provided in this application combines the advantages of well shot and seismic source, employing a well-seismic fusion shot placement method. This method increases the frequency of raw data while controlling costs, utilizing the high resolution of well shot data and the high efficiency of seismic source construction, thus improving economic efficiency. By optimizing the well-seismic ratio, it achieves high-efficiency exploration, increasing the frequency of raw data from the seismic source excitation technology in the Central Depression by approximately 15Hz, meeting the needs of efficient exploration. While improving data resolution, it reduces exploration costs, especially when applied to special terrains such as the Changling fault depression. By designing a suitable well-seismic ratio, it effectively improves the signal-to-noise ratio of high-frequency signals in the Changling fault depression, further broadening the bandwidth of the raw data acquisition, thereby promoting oil and gas discovery and expanding the exploration market. It has broad application prospects and market potential.
[0081] Figure 6 This is a schematic diagram of a device for determining the offset of shot points in an eroded hill area according to another embodiment of this application.
[0082] Based on the same inventive concept, such as Figure 6 As shown in the embodiment of this application, a shot point deployment device is also provided, comprising: a first module for acquiring acquisition task information and observation system parameters, wherein the acquisition task information includes frequency information required by the task, and the observation system parameters include source shot point density; wherein the observation system parameters are parameters used when performing the acquisition task in a source construction manner; a second module for acquiring the design well-to-seismic ratio; wherein the seismic data obtained by construction with the design well-to-seismic ratio meets the requirements of the frequency information; a third module for determining the shot row spacing, shot point location, number of well shot point rows to be deployed, and number of source shot point rows based on the source shot point density and the design well-to-seismic ratio; and a fourth module for deploying the well shot points and the source shot points based on the shot row spacing, the shot point location, the number of well shot point rows, and the number of source shot point rows.
[0083] More details and beneficial effects of this embodiment can be found in the descriptions of the foregoing embodiments, and will not be repeated here.
[0084] Based on the same inventive concept, combined with Figure 11 , Figure 11This is a schematic diagram of the structure of an electronic device according to an embodiment of the present application. In one embodiment, the present application provides an electronic device including a processor 401, a communication interface 402, a memory 403, and a communication bus 404, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; the memory is used to store computer programs; the processor is used to execute the program stored in the memory to implement the shot point layout method or the seismic data acquisition method based on well-seismic fusion shot point design as described above.
[0085] Further details and beneficial effects of this embodiment can be found in the descriptions of the foregoing embodiments, and will not be repeated here. The processor can also be used to process other data or perform calculations. The electronic device can be a PC, server, terminal, or other similar device.
[0086] Any number of the functional modules included in the above-described device can be combined into one module, or any one of the modules can be split into multiple modules. Alternatively, at least part of the functionality of one or more of these modules can be combined with at least part of the functionality of other modules and implemented in one module. At least one of the functional modules included in the above-described device 10 can be at least partially implemented as hardware circuitry, such as a Field Programmable Gate Array (FPGA), a Programmable Logic Array (PLA), a System-on-Chip, a System-on-Substrate, a System-on-Package, an Application-Specific Integrated Circuit (ASIC), or any other reasonable means of integrating or packaging circuitry, or implemented in hardware or firmware, or in any one of software, hardware, and firmware implementations, or in a suitable combination of any of these. Alternatively, at least one of the functional modules included in the device 10 can be at least partially implemented as a computer program module, which, when run, can perform corresponding functions.
[0087] It should be understood that these embodiments are for illustrative purposes only and are not intended to limit the scope of this application. Experimental methods in the following embodiments, unless specific conditions are specified, are generally determined according to national standards. If no corresponding national standard exists, then generally accepted international standards, conventional conditions, or conditions recommended by the manufacturer are followed.
[0088] It should be noted that, in this document, relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element.
[0089] The above description is merely a specific embodiment of this disclosure, enabling those skilled in the art to understand or implement it. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of this disclosure. Therefore, this disclosure is not to be limited to the embodiments shown herein, but is to be accorded the widest scope consistent with the principles and novel features claimed herein.
Claims
1. A method for setting up firing points, characterized in that, include: Acquire acquisition task information and observation system parameters. The acquisition task information includes the frequency information required by the task, and the observation system parameters include the source shot density. The observation system parameters are those used when the acquisition task is performed using a source construction method. Obtain the design well seismic ratio; wherein the seismic data obtained by construction based on the design well seismic ratio meets the requirements of the frequency information; Based on the source shot density and the designed well-seismic ratio, determine the shot row spacing, shot location, number of well shot rows to be deployed, and number of source shot rows; The well-fired blasting points and the seismic source blasting points are deployed according to the blasting row spacing, the blasting point location, the number of blasting point rows in the well, and the number of seismic source blasting point rows.
2. The method for setting up firing points according to claim 1, characterized in that, The method further includes: Obtain multiple different preset well-seismic ratios; For each preset well-seismic ratio, the shot spacing, shot location, number of well shot rows, and number of source shot rows are determined based on the source shot density and the preset well-seismic ratio. Based on the shot row spacing, shot point location, number of shot point rows in the well and number of shot point rows in the seismic source, seismic data corresponding to different preset well-seismic ratios are obtained through simulation calculations. The preset well-seismic ratio that meets the frequency information requirements of the seismic data is used as the design well-seismic ratio.
3. The method for setting up firing points according to claim 2, characterized in that, The step of using the preset well-seismic ratio that conforms to the frequency information requirements of the seismic data as the design well-seismic ratio includes: Based on the frequency information required by the task, determine the highest frequency that the data acquisition task needs to achieve; If the superimposed profile contains a continuous effective signal that can reach the highest frequency, the preset well-to-seismic ratio corresponding to the seismic data to which the superimposed profile belongs is used as the design well-to-seismic ratio.
4. The method for setting up firing points according to claim 3, characterized in that, The method further includes: If there are multiple preset well-seismic ratios that meet the frequency information requirements of the seismic data, then the minimum preset well-seismic ratio among the multiple preset well-seismic ratios shall be taken as the design well-seismic ratio.
5. The method for setting up firing points according to claim 4, characterized in that, The shot row spacing includes the shot row spacing of the well shot points and the shot row spacing of the source shot points. Determining the shot row spacing, shot point locations, the number of well shot point rows and the number of source shot point rows to be deployed based on the source shot point density and the designed well-to-earth ratio includes: The distance between the firing platoons of the seismic source firing points is determined based on the density of the seismic source firing points. The well-shot point density is determined based on the designed well-seismic ratio and the source shot point density. The spacing between the firing points of the well gun is determined based on the density of the well gun firing points. Based on the blast row spacing, the source blast point density, and the well blast point density, determine the blast point location, the number of well blast point rows to be deployed, and the number of source blast point rows.
6. The method for setting up firing points according to claim 5, characterized in that, The ratio of the borehole shot density to the seismic source shot density, rounded down, is equal to the borehole-seismic ratio.
7. A device for setting up firing points, characterized in that, include: The first module is used to acquire acquisition task information and observation system parameters. The acquisition task information includes the frequency information required by the task, and the observation system parameters include the source shot density. The observation system parameters are the parameters when the acquisition task is performed in the manner of source construction. The second module is used to obtain the design well seismic ratio; wherein the seismic data obtained by construction based on the design well seismic ratio meets the requirements of the frequency information. The third module is used to determine the shot row spacing, shot point location, number of well shot row rows and number of source shot row rows to be deployed based on the source shot point density and the design well-seismic ratio. The fourth module is used to deploy the well-fired firing points and the seismic source firing points according to the firing row distance, the firing point location, the number of rows of well-fired firing points, and the number of rows of seismic source firing points.
8. A seismic data acquisition method based on well-seismic fusion shot point design, characterized in that, include: Determine the well-seismic ratio; Using the well-seismic ratio as the design well-seismic ratio, the well shot points and seismic source shot points for performing the acquisition task are deployed using the shot point deployment method according to any one of claims 1 to 6. Based on the well shot point and the seismic source shot point, seismic data that meets the frequency information requirements are obtained.
9. The seismic data acquisition method based on well-seismic fusion shot point design according to claim 7, characterized in that, The determination of the well-seismic ratio includes: Obtain multiple different preset well-seismic ratios; For each preset well-seismic ratio, the shot row spacing, shot point location, number of well shot row positions, and number of source shot row positions are determined based on the total number of shot points and the preset well-seismic ratio. Based on the shot row spacing, shot point location, number of shot point rows in the well and number of shot point rows in the seismic source, seismic data corresponding to different preset well-seismic ratios are obtained through simulation calculations. The preset well-seismic ratio that meets the frequency information requirements of the seismic data is used as the design well-seismic ratio.
10. An electronic device, characterized in that, It includes a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; Memory, used to store computer programs; The processor, when executing a program stored in memory, implements the shot point layout method according to any one of claims 1 to 6 or the seismic data acquisition method based on well-seismic fusion shot point design according to any one of claims 8 to 9.