Three-dimensional formation pressure body determination method, system and equipment and readable storage medium

Abstract

The invention provides a three-dimensional formation pressure body determination method, system and device and a readable storage medium. The three-dimensional formation pressure body determination method comprises the following steps: acquiring depth domain interval velocity data; constructing a three-dimensional interval velocity model based on the depth domain interval velocity data; one-dimensional interval velocities on all measuring lines in the three-dimensional interval velocity model are sequentially sent to terminal equipment, the terminal equipment processes and calculates the one-dimensional interval velocities to form one-dimensional formation pressure data, one-dimensional formation pressure sent by the terminal equipment is received, and the one-dimensional interval velocities on all the measuring lines correspond to one simulation well position; and combining all the one-dimensional formation pressures to obtain a three-dimensional formation pressure body, and calculating the one-dimensional formation pressures by a plurality of terminal devices through a distributed parallel algorithm, so that the operation time is greatly shortened, the operation efficiency is improved, and the one-dimensional interval velocity data of all seismic layers are fully utilized to achieve the purpose of improving the resolution of the formation pressure body.

Description

Technical Field

[0001] The present application belongs to the technical field of oil and gas well engineering, and relates to a method for determining a three-dimensional formation pressure body, and in particular to a method, system, device and readable storage medium for determining a three-dimensional formation pressure body. Background Art

[0002] The traditional formation pressure prediction method is based on one-dimensional layer velocity, and uses the Eaton method to calculate the one-dimensional single-well formation pressure. In engineering practice, the accuracy of one-dimensional formation pressure can generally only be calibrated by the measured values ​​of the formation pressure of the same formation in adjacent wells. Since the one-dimensional formation pressure ignores the lateral variation law of formation characteristics, it may cause large errors. The formation pressure body obtained based on the current formation pressure body prediction method has low resolution and poor accuracy. The traditional calculation method of determining one-dimensional formation pressure based on single-threaded operation in the current formation pressure body prediction method has low computational efficiency. Summary of the invention

[0003] The present application provides a three-dimensional formation pressure body determination method, system, device and readable storage medium to improve the resolution of the formation pressure body and improve the computational efficiency of one-dimensional formation pressure.

[0004] In a first aspect, an embodiment of the present application provides a method for determining a three-dimensional formation pressure body, the method comprising: acquiring depth domain layer velocity data; constructing a three-dimensional layer velocity model based on the depth domain layer velocity data; sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to a terminal device in turn, and receiving the one-dimensional formation pressure sent by the terminal device, wherein the one-dimensional layer velocity on each survey line corresponds to a simulated well location; and merging all of the one-dimensional formation pressures to obtain a three-dimensional formation pressure body.

[0005] In an implementation of the first aspect, constructing a three-dimensional layer velocity model based on the depth-domain layer velocity data includes: determining the abscissa, ordinate, and one-dimensional layer velocity of each survey line in the depth-domain layer velocity data; determining one-dimensional depth data according to a sampling rate of the one-dimensional layer velocity; and obtaining the three-dimensional layer velocity model based on the three-dimensional spatial points corresponding to the abscissa, the ordinate, and the one-dimensional depth data of each survey line.

[0006] In an implementation of the first aspect, sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to a terminal device includes: determining a data body consisting of the abscissa, the ordinate, the one-dimensional layer velocity and the one-dimensional depth data of each survey line; dividing all the data bodies into t data body sets on average; and sending the t data body sets to t terminal devices respectively.

[0007] In an implementation of the first aspect, each of the data sets corresponds to at least one of the one-dimensional formation pressures, and merging all of the one-dimensional formation pressures to obtain a three-dimensional formation pressure body includes: merging the one-dimensional formation pressures corresponding to each of the data sets to obtain the three-dimensional formation pressure body.

[0008] In the three-dimensional formation pressure body determination method provided in the embodiment of the present application, based on the three-dimensional layer velocity model, the data on each survey line in the three-dimensional layer velocity model are sent to the terminal device in turn, and the one-dimensional formation pressure sent by the terminal device is received, and all the one-dimensional formation pressures are merged to obtain a three-dimensional formation pressure body. A high-precision three-dimensional formation pressure body can be constructed without reducing the layer velocity resolution, and all one-dimensional layer velocities at different formation depths in the formation are fully utilized, which has guiding significance for the establishment of fine geological models, drilling engineering design, etc.

[0009] In a second aspect, an embodiment of the present application provides a method for determining a three-dimensional formation pressure body, which is applied to a system including a host and a terminal device, and the method includes: the host obtains depth domain layer velocity data; the host constructs a three-dimensional layer velocity model based on the depth domain layer velocity data; the host sends the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device in turn; the terminal device determines the one-dimensional formation pressure of the current simulated well position based on the received one-dimensional layer velocity, and sends the one-dimensional formation pressure to the host; the host merges all the one-dimensional formation pressures to obtain a three-dimensional formation pressure body.

[0010] In an implementation of the second aspect, the terminal device determines the one-dimensional formation pressure of the current simulated well location based on the received one-dimensional layer velocity, including: determining the overlying rock pressure of the current simulated well location; converting the one-dimensional layer velocity into one-dimensional acoustic wave time difference data; performing data processing on the one-dimensional acoustic wave time difference data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data; and obtaining the one-dimensional formation pressure based on the overlying rock pressure, the normal compaction acoustic wave time difference curve, and the one-dimensional acoustic wave time difference data.

[0011] In an implementation method of the second aspect, the one-dimensional acoustic wave time difference data is processed to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data, including: based on the Mann-Kendall trend test algorithm, automatically determining the one-dimensional decreasing acoustic wave time difference data corresponding to the longest decreasing segment in the one-dimensional acoustic wave time difference data; processing the one-dimensional decreasing acoustic wave time difference data to obtain the logarithmic value corresponding to the one-dimensional decreasing acoustic wave time difference data; and performing regression processing on the logarithmic value of the one-dimensional decreasing acoustic wave time difference data and the one-dimensional depth data to obtain the normal compaction acoustic wave time difference curve.

[0012] In a third aspect, an embodiment of the present application provides an electronic device, comprising a memory and a processor; the memory is used to store a computer program; the processor is used to execute the computer program and implement a three-dimensional formation pressure body determination method as described in any one of the first aspects of the embodiment of the present application when executing the computer program.

[0013] In a fourth aspect, an embodiment of the present application provides a three-dimensional formation pressure body determination system, the system comprising a host and a terminal device, for implementing a three-dimensional formation pressure body determination method as described in any one of the second aspects of the embodiment of the present application.

[0014] In the fifth aspect, an embodiment of the present application provides a computer-readable storage medium having a computer program stored thereon, characterized in that when the computer program is executed by a processor, the three-dimensional formation pressure body determination method described in any one of the first and second aspects of the embodiment of the present application is implemented. BRIEF DESCRIPTION OF THE DRAWINGS

[0015] Figure 1A Shown is an application scenario diagram of a three-dimensional formation pressure body calculation method provided in one embodiment of the present application.

[0016] Figure 1B Shown is a flow chart of a method for determining a three-dimensional formation pressure body provided in one embodiment of the present application.

[0017] Figure 2 Shown is a flow chart of constructing a three-dimensional layer velocity model based on depth-domain layer velocity data in one embodiment of the present application.

[0018] Figure 3 It shows a flow chart of sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device in one embodiment of the present application.

[0019] Figure 4 Shown is a flow chart of another three-dimensional formation pressure body determination method provided in one embodiment of the present application.

[0020] Figure 5 Shown is a flow chart of a terminal device provided in one embodiment of the present application determining the one-dimensional formation pressure of the current simulated well position based on the received one-dimensional layer velocity.

[0021] Figure 6 Shown is a flow chart of processing one-dimensional acoustic wave time difference data provided in an embodiment of the present application to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data.

[0022] Figure 7 Shown is a flow chart of another three-dimensional formation pressure body determination method provided in one embodiment of the present application.

[0023] Figure 8 Shown is a schematic diagram of a three-dimensional formation pressure body provided in one embodiment of the present application.

[0024] Fig. 9 Shown is a cross-sectional view of a three-dimensional formation pressure body provided in one embodiment of the present application.

[0025] Fig.10 Shown is a path diagram of a three-dimensional formation pressure body determination method provided in one embodiment of the present application.

[0026] Fig.11 Shown is a schematic diagram of the structure of an electronic device in an embodiment of the present application.

[0027] Component number description

[0028] Steps S11 to S14

[0029] Steps S21 to S23

[0030] Steps S31 to S33

[0031] Steps S41 to S45

[0032] Steps S51 to S54

[0033] Steps S61 to S63

[0034] Steps S71 to S75

[0035] 11 Electronic devices

[0036] 110 Processor

[0037] 120 System bus

[0038] 130 Network Interface

[0039] 140 Non-volatile storage media

[0040] 150 Internal memory DETAILED DESCRIPTION

[0041] The following describes the embodiments of the present application through specific examples, and those skilled in the art can easily understand other advantages and effects of the present application from the contents disclosed in this specification. The present application can also be implemented or applied through other different specific embodiments, and the details in this specification can also be modified or changed in various ways based on different viewpoints and applications without departing from the spirit of the present application. It should be noted that the following embodiments and features in the embodiments can be combined with each other without conflict.

[0042] It should be noted that the illustrations provided in the following embodiments are only schematic illustrations of the basic concept of the present application, and thus the drawings only show components related to the present application rather than being drawn according to the number, shape and size of components in actual implementation. In actual implementation, the form, quantity and proportion of each component may be changed arbitrarily, and the component layout may also be more complicated.

[0043] The embodiment of the present application provides a method for determining a three-dimensional formation pressure body. The method for determining a three-dimensional formation pressure body can obtain depth domain layer velocity data; construct a three-dimensional layer velocity model based on the depth domain layer velocity data; sequentially send the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to a terminal device, receive the one-dimensional formation pressure sent by the terminal device, wherein the one-dimensional layer velocity on each survey line corresponds to a simulated well position; merge all the one-dimensional formation pressures to obtain a three-dimensional formation pressure body, so as to solve the technical problem in the prior art that the lateral variation law of formation characteristics is ignored when calculating the one-dimensional formation pressure, which may cause large errors, and achieve the purpose of improving the resolution of the formation pressure body and improving the calculation efficiency of the one-dimensional formation pressure.

[0044] Figure 1A This is a diagram showing an application scenario of a three-dimensional formation pressure body calculation method provided in an embodiment of the present application. Figure 1A As shown, the application scenario includes a host and a terminal device. The host and the terminal device are connected in communication.

[0045] The host is used to send the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device. The terminal device is used to determine the one-dimensional formation pressure of the current simulated well position according to the received one-dimensional layer velocity, and send the one-dimensional formation pressure to the host.

[0046] The host in the embodiment of the present application may be: a mainframe, a minicomputer, a laptop, a desktop computer and other electronic devices. The terminal device in the embodiment of the present application may be: a physical terminal device and a virtual terminal device. For example, the physical terminal device includes: a personal computer, a supercomputer, etc., and the virtual terminal device includes a virtual machine, etc.

[0047] The technical solutions in the embodiments of the present application will be described in detail below in conjunction with the drawings in the embodiments of the present application.

[0048] Figure 1B The flowchart of the method for determining a three-dimensional formation pressure body provided by an embodiment of the present application is shown. Figure 1B As shown, the three-dimensional formation pressure body determination method provided in the embodiment of the present application includes the following steps S11 to S14.

[0049] S11, obtaining depth domain layer velocity data.

[0050] Among them, the depth domain layer velocity refers to the velocity parameter related to the formation depth in seismic data processing, which is specifically manifested as the propagation speed of seismic waves in formations at different depths underground.

[0051] For example, the depth domain layer velocity data may be acquired based on any one of acoustic logging and seismic logging tools.

[0052] Exemplarily, the depth domain layer velocity data may also be acquired based on any one of a tomographic velocity modeling method, a seismic velocity analysis method, and the like.

[0053] Specifically, the number of depth domain layer velocity data obtained based on any one of acoustic logging and seismic logging tools or based on any one of a tomographic velocity modeling method and a seismic velocity analysis method is at least one.

[0054] It should be noted that the above-mentioned tools or methods for obtaining depth domain layer velocity data are only used for illustrative purposes. In practical applications, any other suitable methods or tools may be selected, and this application does not impose any limitation on this.

[0055] S12, constructing a three-dimensional layer velocity model based on the depth domain layer velocity data.

[0056] Specifically, after the depth domain layer velocity data is acquired, a three-dimensional layer velocity model is constructed based on the depth domain layer velocity data at different formation depths.

[0057] Exemplarily, after obtaining the depth domain layer velocity data, the depth domain layer velocity data is preprocessed to ensure the integrity of the data, wherein the preprocessing includes: one or more of: denoising, data interpolation, etc. An initial three-dimensional layer velocity model is established based on the existing depth domain layer velocity data, wherein the specific method of establishing the initial three-dimensional layer velocity model can be based on an interpolation method, such as Kriging interpolation or polygonal mesh interpolation, to expand the well point data into three-dimensional space. The three-dimensional layer velocity model is optimized by pre-stack or post-stack velocity analysis. The accuracy of the three-dimensional layer velocity model is verified by comparing the layer velocity data predicted by the three-dimensional layer velocity model with the actual layer velocity data. When the data error between the layer velocity data predicted by the three-dimensional layer velocity model and the actual layer velocity data is within the allowable error range, it means that the accuracy of the constructed three-dimensional layer velocity model is verified, and the final three-dimensional layer velocity model is obtained.

[0058] It should be noted that the specific numerical value of the allowable error range corresponding to the data error between the layer velocity data predicted by the above three-dimensional layer velocity model and the actual layer velocity data can be reasonably set according to actual conditions, and this application does not impose any restrictions on this.

[0059] S13, sending the one-dimensional layer velocity on each measuring line in the three-dimensional layer velocity model to the terminal device in turn, and receiving the one-dimensional formation pressure sent by the terminal device.

[0060] The one-dimensional layer velocity on each survey line corresponds to a simulated well position, and the formation pressure profile of the simulated well position can be calculated based on the one-dimensional layer velocity.

[0061] Each survey line represents a specific seismic data acquisition trajectory or a virtual path.

[0062] For example, before sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device, the one-dimensional layer velocity may be converted into a data type that can be received by the terminal device. For example, the data type of the one-dimensional layer velocity may be converted into a data format that can be received by the terminal device, such as CSV, LAS, and / or JSON.

[0063] Specifically, a suitable communication protocol can be used to send the converted one-dimensional layer speed to the terminal device to ensure the security of the data transmission process. The suitable communication protocol can be any one of the File Transfer Protocol (FTP), Hypertext Transfer Protocol (HTTP) and / or WebSocket Protocol.

[0064] It should be noted that the communication protocols listed above are only for illustrative purposes. In practical applications, any other suitable communication protocol may be selected, and this application does not impose any limitation on this.

[0065] Specifically, based on the same or different communication protocol as the above, the one-dimensional formation pressure corresponding to the one-dimensional layer velocity sent by the terminal device can be received.

[0066] S14, combining all the one-dimensional formation pressures to obtain a three-dimensional formation pressure body.

[0067] Specifically, after all the one-dimensional formation pressures are obtained, all the one-dimensional formation pressures are directly superimposed to obtain a three-dimensional formation pressure body. Specifically, based on the abscissa, ordinate and horizontal depth corresponding to each one-dimensional formation pressure, the position coordinates of each one-dimensional formation pressure in the three-dimensional space composed of the abscissa, ordinate and horizontal depth are determined. Based on the position coordinates of each one-dimensional formation pressure in the three-dimensional space, a three-dimensional formation pressure body is obtained.

[0068] In the three-dimensional formation pressure body determination method provided in the embodiment of the present application, depth domain layer velocity data is obtained; based on the depth domain layer velocity data, a three-dimensional layer velocity model is constructed; the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model is sequentially sent to a terminal device, and the one-dimensional formation pressure sent by the terminal device is received, wherein the one-dimensional layer velocity on each survey line corresponds to a simulated well position; all the one-dimensional formation pressures are merged to obtain a three-dimensional formation pressure body, and the one-dimensional layer velocities corresponding to different horizontal and vertical coordinates on each survey line may be different. According to different one-dimensional layer velocities, the one-dimensional formation pressure corresponding to each one-dimensional layer velocity is obtained respectively, and all the one-dimensional formation pressures are merged to obtain a three-dimensional formation pressure body, which solves the technical problem in the prior art that the lateral variation law of formation characteristics is ignored when calculating the one-dimensional formation pressure, which may cause large errors.

[0069] Figure 2 The flowchart of constructing a three-dimensional layer velocity model based on depth domain layer velocity data in one embodiment of the present application is shown. Figure 2 As shown, in the embodiment of the present application, the process of constructing a three-dimensional layer velocity model based on the depth domain layer velocity data includes the following steps S21 to S23.

[0070] S21, determining the abscissa, ordinate and one-dimensional layer velocity of each survey line in the depth domain layer velocity data.

[0071] There are multiple depth domain layer velocity data, and each depth domain layer velocity data corresponds to a survey line.

[0072] Specifically, after determining the survey line corresponding to the depth domain layer velocity data, the horizontal coordinate, vertical coordinate and one-dimensional layer velocity of each survey line can be determined in turn based on the geographic information system software. The geographic information system software can be one or more of GRASS GIS, SAGA GIS, Manifold System, etc.

[0073] It should be noted that the geographic information system software listed above is only for illustrative purposes. In actual applications, any other suitable geographic information system software may be selected, and this application does not impose any limitation on this.

[0074] S22, determining one-dimensional depth data according to the sampling rate of the one-dimensional layer velocity.

[0075] The sampling rate of one-dimensional layer velocity refers to the data interval when collecting one-dimensional layer velocity.

[0076] For example, a one-dimensional layer velocity is extracted at 0.5m, and the stratum depth when the one-dimensional layer velocity extraction starts is 1000m. A total of 20 one-dimensional layer velocities are extracted, and different one-dimensional layer velocity and one-dimensional depth data are extracted at a data interval of 0.5m in the direction of the underground. When the 10th one-dimensional layer velocity is completed, the corresponding one-dimensional depth data is 1005m; when the 20th one-dimensional layer velocity is completed, the corresponding one-dimensional depth data is 1010m. That is, the sampling rate of the one-dimensional layer velocity is 0.5m, the one-dimensional depth data corresponding to the 10th one-dimensional layer velocity is 1005m, and the one-dimensional depth data corresponding to the 20th one-dimensional layer velocity is 1010m. Similarly, the one-dimensional depth data corresponding to the other 18 one-dimensional layer velocities can be obtained, which will not be repeated in this application.

[0077] It should be noted that the specific values ​​of the sampling rates and one-dimensional depth data corresponding to different one-dimensional layer velocities given in the above embodiments are only for illustrative purposes and are not limited in the present application.

[0078] S23, obtaining the three-dimensional layer velocity model based on the abscissa, the ordinate and the three-dimensional space point corresponding to the one-dimensional depth data of each survey line.

[0079] Specifically, after the abscissa, ordinate and one-dimensional depth data of each survey line are determined, the three-dimensional layer velocity model is determined according to the three-dimensional space points corresponding to the abscissa, ordinate and one-dimensional depth data of each survey line.

[0080] For example, if the measuring line L 11 The horizontal axis is x 11 , the vertical coordinate is y 11 , the one-dimensional depth data is D 11 , measuring line L 11 Medium (x 11 ,y 11 , D 11 ) is located at a three-dimensional space point corresponding to a one-dimensional layer velocity V 11 ; Measurement line L 12 The horizontal axis is x 12 , the vertical coordinate is y 12 and one-dimensional depth data D 12 , measuring line L 12 Medium (x 12 ,y 12 , D 12 ) is located at a three-dimensional space point corresponding to a one-dimensional layer velocity V 12 ;......;Measurement line L 1n The horizontal axis is x 1n , the vertical coordinate is y 1n , the one-dimensional depth data is D 1n , measuring line L 1n Medium (x1n ,y 1n , D 1n ) is located in the three-dimensional space, and the corresponding one-dimensional layer velocity is V 1n . Measuring line L 21 The horizontal axis is x 21 , the vertical coordinate is y 21 , the one-dimensional depth data is D 21 , measuring line L 21 Medium (x 21 ,y 21 , D 21 ) corresponds to the one-dimensional layer velocity V 21 ; Measurement line L 22 The horizontal axis is x 22 , the vertical coordinate is y 22 , the one-dimensional depth data is D 22 , measuring line L 22 Medium (x 22 ,y 22 , D 22 ) is located in the three-dimensional space, and the corresponding one-dimensional layer velocity is V 22 ;......;Measurement line L 2n The horizontal axis is x 2n , the vertical coordinate is y 2n , the one-dimensional depth data is D 2n , measuring line L 2n Medium (x 2n ,y 2n , D 2n ) is located at a three-dimensional space point corresponding to a one-dimensional layer velocity V 2n . Measuring line L n1 The horizontal axis is x n1 , the vertical coordinate is y n1 , the one-dimensional depth data is D n1 , measuring line L n1 Medium (x n1 ,y n1 , D n1 ) is located in the three-dimensional space, and the corresponding one-dimensional layer velocity is V n1 ; Measurement line L n2 The horizontal axis is x n2 , the vertical coordinate is y n2 , the one-dimensional depth data is D n2 , measuring line L n2 Medium (x n2 ,y n2 , D n2 ) is located in the three-dimensional space, and the corresponding one-dimensional layer velocity is V n2 ;......;Measurement line L nn The horizontal axis is x nn , the vertical coordinate is y nn, the one-dimensional depth data is D nn , measuring line L nn Medium (x nn ,y nn , D nn ) is located at a three-dimensional space point corresponding to a one-dimensional layer velocity V nn , where n represents the number of measurement lines. According to the above V 11 、V 12 ,......,V 1n 、V 21 、V 22 ,......,V 2n ,......V n1 、V n2 ,......,V nn , and a three-layer velocity model is obtained.

[0081] It should be noted that the number of the above-mentioned survey lines and the number of one-dimensional layer velocities corresponding to each survey line can be reasonably set according to specific circumstances, and this application does not impose any restrictions on this.

[0082] In the method for constructing a three-dimensional layer velocity model based on depth-domain layer velocity data provided in an embodiment of the present application, the horizontal coordinate, vertical coordinate and one-dimensional layer velocity of each survey line in the depth-domain layer velocity are determined; the one-dimensional depth data is determined according to the sampling rate of the one-dimensional layer velocity; the three-dimensional layer velocity model is obtained based on the three-dimensional spatial points corresponding to the horizontal coordinate, the vertical coordinate and the one-dimensional depth data of each survey line, and the horizontal and vertical variation laws of different formation characteristics are fully utilized, the accuracy of establishing the three-dimensional layer velocity model is improved, and an accurate data basis is provided for the subsequent calculation of the one-dimensional formation pressure corresponding to each one-dimensional layer velocity based on each one-dimensional layer velocity in the three-dimensional layer velocity model.

[0083] Figure 3 The flowchart of sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device in one embodiment of the present application is shown. Figure 3 As shown, in the embodiment of the present application, the process of sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device includes the following steps S31 to S33.

[0084] S31, determining a data volume consisting of the abscissa, the ordinate, the one-dimensional layer velocity and the one-dimensional depth data of each survey line.

[0085] For example, the measuring line L 11 The abscissa, the ordinate, the one-dimensional layer velocity and the one-dimensional depth data are marked as [x 11 ,y 11 , D 11 , V11 ]、[x 12 ,y 12 , D 12 , V 12 ],......,[x 1n ,y 1n , D 1n , V 1n ], then [x 11 ,y 11 , D 11 , V 11 ] is the data body S 11 ,[x 12 ,y 12 , D 12 , V 12 ] is the data body S 12 ,[x 1n ,y 1n , D 1n , V 1n ] is the data body S 1n Similarly, we can get the data body S 21 , data body S 22 ,.......,Data Body S nn .

[0086] It should be noted that the number of the above data volumes is determined by the number of one-dimensional layer velocities.

[0087] Exemplarily, an example of a data volume corresponding to an XY-dimensional layer velocity is given in Table 1, where X represents the abscissa of the survey line and Y represents the ordinate of the survey line, as shown in the following table.

[0088] Table 1. Example of data volume corresponding to X-Y one-dimensional layer velocity

[0089] Serial number X Y One-dimensional layer velocity corresponding to different one-dimensional depth data 1 386456.031 1930623.75 [1542.8351542.96291542.835...2848.76372849.45042850.04] 2 386373.468 1930524.125 [1542.87351543.0131542.873...2848.51222849.22492849.8242] 3 386290.906 1930424.375 [1542.75491542.90971542.77...2848.3092849.04422849.6519] 4 386208.343 1930324.625 [1542.97491543.09771542.9216...2848.10622848.85182849.4631] 5 386125.781 1930224.875 [1542.61871542.74711542.6904...2847.8792848.61162849.2183] 6 386043.218 1930125.25 [1543.10011543.12111543.0332...2847.612848.32252848.9216] 7 385960.656 1930025.5 [1542.37351542.34251542.3442...2847.30622848.0052848.5989] 8 385878.093 1929925.75 [1542.45951542.27711542.1833...2847.00932847.69922848.29] 9 385795.531 1929826.125 [1541.62161541.3751541.322...2846.76882847.44952848.0369] 10 385712.968 1929726.375 [1541.57711541.24461541.1104...2846.47442847.1392847.7217] … … … … 3345672 385630.406 1929626.625 [1540.48461540.29831540.3066...2846.1642846.8022847.3772]

[0090] S32, dividing all the data volumes into t data volume sets on average, where t is an integer greater than 2.

[0091] Among them, the t data sets are independent of each other.

[0092] Preferably, the memory space of each data set is less than 1 / 4 of the total available memory of the computer.

[0093] S33, sending the t data sets to t terminal devices respectively.

[0094] Specifically, t data sets are sent to t terminal devices respectively based on a network transmission protocol.

[0095] In some possible implementations, each of the data sets corresponds to at least one one-dimensional formation pressure, and merging all of the one-dimensional formation pressures to obtain a three-dimensional formation pressure body includes: merging the one-dimensional formation pressures corresponding to each of the data sets to obtain the three-dimensional formation pressure body.

[0096] Specifically, the one-dimensional formation pressure corresponding to the data set received by the host is combined by a data processing system in the host with the one-dimensional formation pressure corresponding to each data set to obtain a three-dimensional formation pressure body.

[0097] It should be noted that the above-mentioned data processing system can be any suitable system that realizes the function of merging the one-dimensional formation pressures corresponding to each data set within a host computer, and the present application does not impose any limitation on this.

[0098] In the method for sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device provided in the embodiment of the present application, by determining the data body composed of the horizontal coordinate, the vertical coordinate, the one-dimensional layer velocity and the one-dimensional depth data of each survey line, all of the data bodies are evenly divided into t data body sets, and the t data body sets are respectively sent to t terminal devices, thereby providing an accurate and complete data basis for the terminal device to efficiently calculate the one-dimensional formation pressure corresponding to the one-dimensional layer velocity.

[0099] Figure 4 The flowchart of another method for determining a three-dimensional formation pressure body provided in one embodiment of the present application is shown, and the method is applied to a system including a host and a terminal device. Figure 4 As shown, the process of the flowchart of another three-dimensional formation pressure body determination method provided in one embodiment of the present application includes the following steps S41 to S45.

[0100] S41, the host obtains depth domain layer velocity data.

[0101] Specifically, the host can obtain depth domain layer velocity data through any method such as a tomographic velocity modeling method and a seismic velocity analysis method.

[0102] S42, the host constructs a three-dimensional layer velocity model based on the depth domain layer velocity data.

[0103] S43, the host sends the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device in sequence.

[0104] S44, the terminal device determines the one-dimensional formation pressure of the current simulated well position according to the received one-dimensional layer velocity, and sends the one-dimensional formation pressure to the host.

[0105] Specifically, t terminal devices receive t data sets respectively. Based on the distributed parallel algorithm, the t terminal devices simultaneously calculate the received data sets, which greatly shortens the operation time. Each terminal device calculates the one-dimensional formation pressure corresponding to each row of data [X, Y, V, D] in the data set in turn, and calculates all [X, Y, P p ] Return to the host computer. Table 2 shows an example table of XY-dimensional formation pressure.

[0106] Table 2 X-Y-One-dimensional formation pressure example table

[0107] Serial number X Y One-dimensional depth data One-dimensional formation pressure 1 386456.031 1930623.75 [0510...548554905495] [11.0491.049...2.132.1312.131] 2 386373.468 1930524.125 [0510...548554905495] [11.0491.049...2.132.1312.131] 3 386290.906 1930424.375 [0510...548554905495] [11.0491.049...2.132.132.13] 4 386208.343 1930324.625 [0510...548554905495] [11.0491.049...2.132.132.13] 5 386125.781 1930224.875 [0510...548554905495] [11.0491.049...2.1292.132.13] 6 386043.218 1930125.25 [0510...548554905495] [11.0491.049...2.1292.132.13] 7 385960.656 1930025.5 [0510...548554905495] [11.0491.049...2.1292.132.13] 8 385878.093 1929925.75 [0510...548554905495] [11.0491.049...2.1292.132.13] 9 385795.531 1929826.125 [0510...548554905495] [11.0491.049...2.1292.1292.13] 10 385712.968 1929726.375 [0510...548554905495] [11.0491.049...2.1292.1292.129] … … … … … 3345672 385630.406 1929626.625 [0510...548554905495] [11.0491.049...2.1262.1272.127]

[0108] For example, in the terminal device, the one-dimensional formation pressure of the current simulated well position may be determined based on the Eaton method or the Bowers method.

[0109] S45, the host computer combines all the one-dimensional formation pressures to obtain a three-dimensional formation pressure body.

[0110] Exemplarily, all of the one-dimensional formation pressures are input into the three-dimensional formation visualization model to obtain a three-dimensional formation pressure body schematic diagram, such as Figure 8 shown.

[0111] In addition, the cross-sectional representation of the three-dimensional formation pressure body can be found in Fig. 9 .

[0112] In another method for determining a three-dimensional formation pressure body provided by an embodiment of the present application, the host obtains depth domain layer velocity data; the host constructs a three-dimensional layer velocity model based on the depth domain layer velocity data; the host sends the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device in turn; the terminal device determines the one-dimensional formation pressure of the current simulated well position based on the received one-dimensional layer velocity, and sends the one-dimensional formation pressure to the host; the host merges all the one-dimensional formation pressures to obtain a three-dimensional formation pressure body, and based on the communication connection between the host and the terminal device, the host sends the obtained one-dimensional layer velocity and other data to the terminal device in a timely manner to perform data calculation inside the terminal device. The host is mainly used to obtain one-dimensional layer velocity and other data. Based on the distributed parallel algorithm, multiple terminal devices can simultaneously calculate the received data set, which greatly shortens the calculation time. The terminal device mainly calculates based on the one-dimensional layer velocity and other data to obtain the one-dimensional formation pressure. The host and the terminal device are both independent of each other and cooperate with each other, which can realize efficient data processing and calculation and improve the efficiency of realizing the three-dimensional formation pressure body.

[0113] Figure 5The flowchart shown is a flow chart of a terminal device according to an embodiment of the present application determining the one-dimensional formation pressure of the current simulated well position based on the received one-dimensional layer velocity. Figure 5 As shown, the process of determining the one-dimensional formation pressure of the current simulated well position according to the received one-dimensional layer velocity by the terminal device provided in one embodiment of the present application includes the following steps S51 to S54.

[0114] S51, determining the overlying rock pressure of the current simulated well location.

[0115] Specifically, the formula for determining the overburden pressure at the current simulated well position is:

[0116]

[0117] Wherein, OBG represents the overburden pressure, ρ represents the one-dimensional formation density data, h represents the formation depth, and g represents the gravitational acceleration.

[0118] The expression corresponding to the one-dimensional formation density data is:

[0119] ρ=AV B

[0120] Wherein, V represents the one-dimensional interval velocity, and the values ​​of parameters A and B are calibrated by density logging data of adjacent wells in the same block, for example, A=0.75, B=0.25.

[0121] It should be noted that the specific values ​​of A and B mentioned above may also be any other suitable values, and this application does not impose any limitation on this.

[0122] In particular, for the marine block, when considering the influence of water depth, the formula corresponding to the overburden pressure at the current simulated well location is:

[0123]

[0124] Among them, ρ ω represents the density of seawater, and h1 represents the depth of seawater.

[0125] S52, converting the one-dimensional layer velocity into one-dimensional acoustic wave time difference data.

[0126] Specifically, the formula corresponding to converting the one-dimensional layer velocity into one-dimensional acoustic wave time difference data is:

[0127]

[0128] Wherein, V represents one-dimensional layer velocity, DT represents one-dimensional acoustic wave time difference data, and the unit of DT is (us / ft).

[0129] S53, performing data processing on the one-dimensional acoustic wave time difference data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data.

[0130] Specifically, the data processing includes: determining the longest decreasing segment of DT and marking it as DT', which is the one-dimensional decreasing acoustic wave time difference data. Performing logarithmic processing on DT', and performing regression processing based on DT' and one-dimensional depth data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data.

[0131] S54, obtaining the one-dimensional formation pressure based on the overburden pressure, the normal compaction acoustic wave time difference curve, and the one-dimensional acoustic wave time difference data.

[0132] Specifically, based on the overburden pressure, the normal compaction acoustic wave time difference curve, and the one-dimensional acoustic wave time difference data, the formula corresponding to the one-dimensional formation pressure is obtained as follows:

[0133]

[0134] Among them, P w Indicates the formation water density equivalent, n represents the Eaton coefficient, DT n Represents the normal compaction acoustic wave time difference curve, P P Represents one-dimensional formation pressure.

[0135] For example, P w It can be taken as 1.06, and n can be taken as 0.8~3.0.

[0136] It should be noted that the above P w The specific values ​​of and n can also be reasonably determined based on the specific circumstances, and this application does not impose any restrictions on this.

[0137] In the method provided by the terminal device in the embodiment of the present application, for determining the one-dimensional formation pressure of the current simulated well position based on the received one-dimensional layer velocity, the overlying stratum pressure of the current simulated well position is determined; the current layer velocity is converted into one-dimensional acoustic wave time difference data; the one-dimensional acoustic wave time difference data is processed to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data; the one-dimensional formation pressure is obtained based on the overlying stratum pressure, the normal compaction acoustic wave time difference curve, and the one-dimensional acoustic wave time difference data; the one-dimensional formation pressure is finally obtained by sequential calculation based on multiple specific formulas, thereby ensuring the accuracy of the finally obtained one-dimensional formation pressure.

[0138] Figure 6 The flowchart shown is a flow chart of processing one-dimensional acoustic wave time difference data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data provided in an embodiment of the present application. Figure 6As shown, the process of performing data processing on one-dimensional acoustic wave time difference data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data provided in one embodiment of the present application includes the following steps S61 to S63.

[0139] S61, based on the Mann-Kendall trend test algorithm, automatically determine the one-dimensional decreasing acoustic wave time difference data corresponding to the longest decreasing segment in the one-dimensional acoustic wave time difference data.

[0140] For example, based on the Mann-Kendall (MK) trend test algorithm, the increasing and decreasing trend of the one-dimensional vector DT can be automatically determined in segments, and all decreasing segments can be marked. The longest decreasing segment DT' is found in the depth domain, and DT' is the one-dimensional decreasing acoustic wave time difference data. The MK trend test algorithm can solve the problem of automatic identification of normal compaction segments.

[0141] S62, performing data processing on the one-dimensional decreasing sound wave time difference data to obtain a logarithmic value corresponding to the one-dimensional decreasing sound wave time difference data.

[0142] The data processing of the one-dimensional decreasing sound wave time difference data is specifically to perform logarithmic processing on the one-dimensional decreasing sound wave time difference data.

[0143] Specifically, after logarithmic processing is performed on the one-dimensional decreasing sound wave time difference data DT', a logarithmic value corresponding to the one-dimensional decreasing sound wave time difference data is obtained, and the logarithmic value corresponding to the one-dimensional decreasing sound wave time difference data is In(DT').

[0144] S63, performing regression processing on the logarithmic value of the one-dimensional decreasing acoustic wave time difference data and the one-dimensional depth data to obtain the normal compaction acoustic wave time difference curve.

[0145] Exemplarily, the above-mentioned regression processing of the logarithmic value of the one-dimensional decreasing acoustic wave time difference data and the one-dimensional depth data may be specifically performed as linear regression.

[0146] It should be noted that the above-mentioned regression processing is specifically linear regression and is only used for illustrative purposes. The regression processing can obtain the normal compaction sound wave time difference curve required by the embodiment of the present application. The present application does not limit the specific regression processing method.

[0147] Specifically, the normal compaction acoustic wave time difference curve is expressed as DT n .

[0148] In an embodiment of the present application, a method is provided for processing one-dimensional acoustic wave time difference data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data. Based on the Mann-Kendall trend test algorithm, the one-dimensional decreasing acoustic wave time difference data corresponding to the longest decreasing segment in the one-dimensional acoustic wave time difference data is automatically determined; the one-dimensional decreasing acoustic wave time difference data is processed to obtain a logarithmic value corresponding to the one-dimensional decreasing acoustic wave time difference data; the logarithmic value of the one-dimensional decreasing acoustic wave time difference data and the one-dimensional depth data are regressed to obtain the normal compaction acoustic wave time difference curve, which provides a data basis for the subsequent calculation of the one-dimensional formation pressure corresponding to each one-dimensional layer velocity.

[0149] It should be noted that the path diagram of the method for determining the three-dimensional formation pressure body can be found in Fig.10 The specific implementation process is similar to the method or steps in the above embodiment, and this application will not repeat them here.

[0150] Figure 7 It is a flow chart showing another method for determining a three-dimensional formation pressure body provided in one embodiment of the present application. Figure 7 The methods and steps have been introduced in the above embodiments and will not be repeated in this application.

[0151] The protection scope of the three-dimensional formation pressure body determination method of the embodiment of the present application is not limited to the execution order of the steps listed in this embodiment. All solutions implemented by adding, reducing or replacing steps in the prior art based on the principles of the present application are included in the protection scope of the present application.

[0152] In the several embodiments provided in the present application, it should be understood that the disclosed system or method can be implemented in other ways. For example, the device embodiments described above are only schematic. For example, the division of modules / units is only a logical function division. There may be other division methods in actual implementation, such as multiple modules or units can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be an indirect coupling or communication connection through some interfaces, devices or modules or units, which can be electrical, mechanical or other forms.

[0153] The modules / units described as separate components may or may not be physically separated, and the components displayed as modules / units may or may not be physical modules, that is, they may be located in one place, or they may be distributed on multiple network units. Some or all of the modules / units may be selected according to actual needs to achieve the purpose of the embodiments of the present application. For example, the functional modules / units in the various embodiments of the present application may be integrated into one processing module, or each module / unit may exist physically separately, or two or more modules / units may be integrated into one module / unit.

[0154] Those of ordinary skill in the art should further appreciate that the units and steps of each example described in conjunction with the embodiments disclosed herein can be implemented with electronic hardware, computer software, or a combination of the two. In order to clearly illustrate the interchangeability of hardware and software, the composition and steps of each example have been generally described in terms of function in the above description. Whether these functions are performed in hardware or software depends on the specific application and design constraints of the technical solution. Professional and technical personnel can use different methods to implement the described functions for each specific application, but such implementation should not be considered to be beyond the scope of this application.

[0155] The present application embodiment also provides a computer-readable storage medium. A person of ordinary skill in the art can understand that all or part of the steps in the method for implementing the above embodiment can be completed by instructing the processor through a program, and the program can be stored in a computer-readable storage medium. The storage medium is a non-transitory medium, such as a random access memory, a read-only memory, a flash memory, a hard disk, a solid-state hard disk, a magnetic tape, a floppy disk, an optical disc, and any combination thereof. The above storage medium can be any available medium that can be accessed by a computer or a data storage device such as a server or a data center that includes one or more available media integrated. The available medium can be a magnetic medium (e.g., a floppy disk, a hard disk, a tape), an optical medium (e.g., a digital video disc (DVD)), or a semiconductor medium (e.g., a solid-state disk (SSD)), etc.

[0156] An embodiment of the present application also provides an electronic device. Fig.11 The structure diagram of the electronic device 11 in one embodiment of the present application is shown as follows: The three-dimensional formation pressure body determination method provided in the embodiment of the present application can be applied to Fig.11 The electronic device 11 shown in the figure is not limited thereto. Fig.11As shown, the electronic device 11 includes a processor 110 , a memory, a system bus 120 , and a network interface 130 , wherein the memory may include a non-volatile storage medium 140 and an internal memory 150 .

[0157] The non-volatile storage medium 140 can store an operating system and a computer program. The computer program includes program instructions, and when the program instructions are executed, the processor can execute any one of the three-dimensional formation pressure body determination methods provided in the embodiments of the present application.

[0158] The processor is used to provide computing and control capabilities and support the operation of the entire computer equipment.

[0159] The internal memory 150 provides an environment for the operation of the computer program in the non-volatile storage medium. When the computer program is executed by the processor, the processor can execute any one of the three-dimensional formation pressure body determination methods provided in the embodiments of the present application.

[0160] The network interface 130 is used for network communication, such as sending assigned tasks, etc. Those skilled in the art will appreciate that Fig.11 The structure shown in the figure is only a block diagram of a part of the structure related to the solution of the present application, and does not constitute a limitation on the computer device to which the solution of the present application is applied. The specific computer device may include more or fewer components than those shown in the figure, or combine certain components, or have a different arrangement of components.

[0161] It should be understood that the processor 110 may be a central processing unit (CPU), and the processor may also be other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. Among them, the general-purpose processor may be a microprocessor or the processor may also be any conventional processor, etc.

[0162] The electronic device 11 of the embodiment of the present application may include a tablet computer, a laptop computer, a smart phone, a supercomputer, etc., and can also be applied to databases, servers, and service response systems based on terminal artificial intelligence. The embodiment of the present application does not impose any restrictions on the specific type of electronic device.

[0163] For example, the electronic device can be a station (STAION, ST) in a WLAN, a cellular phone, a cordless phone, a Session Initiation Protocol (SIP) phone, a Wireless Local Loop (WLL) station, a handheld device with wireless communication function, a computing device or other processing device connected to a wireless modem, a computer, a laptop computer, a handheld communication device, a handheld computing device, and / or other devices for communicating on wireless systems and next-generation communication systems, such as mobile terminals in 5G networks, mobile terminals in future evolved public land mobile networks (Public Land Mobile Network, PLMN) or mobile terminals in future evolved non-terrestrial networks (Non-terrestrial Network, NTN), etc.

[0164] As an example but not limitation, when the electronic device is a wearable device, the wearable device can also be a general term for wearable devices that are intelligently designed and developed using wearable technology for daily wear, such as gloves and watches equipped with near-field communication modules. A wearable device is a portable device that is worn directly on the body or integrated into the user's clothes or accessories. It is attached to the user and performs payment, authentication and other operations through a pre-bound electronic card. Wearable devices are not only hardware devices, but also powerful functions achieved through software support, data interaction, and cloud interaction. Broadly speaking, wearable smart devices include those that are fully functional, large in size, and can achieve complete or partial functions without relying on smartphones, such as smart watches or smart glasses, as well as those that only focus on a certain type of application function and need to be used in conjunction with other devices such as smartphones, such as various types of smart watches and smart bracelets with display screens.

[0165] The descriptions of the processes or structures corresponding to the above-mentioned figures have different emphases. For parts that are not described in detail in a certain process or structure, please refer to the relevant descriptions of other processes or structures.

[0166] The above embodiments are merely illustrative of the principles and effects of the present application and are not intended to limit the present application. Anyone familiar with the technology may modify or change the above embodiments without violating the spirit and scope of the present application. Therefore, all equivalent modifications or changes made by a person of ordinary skill in the art without departing from the spirit and technical ideas disclosed in the present application shall still be covered by the claims of the present application.

Claims

1. A method for determining a three-dimensional formation pressure body, characterized in that: Applied to a host, the method comprises: Obtaining depth domain layer velocity data; Based on the depth domain layer velocity data, construct a three-dimensional layer velocity model; sequentially sending the one-dimensional layer velocity on each measuring line in the three-dimensional layer velocity model to a terminal device, and receiving the one-dimensional formation pressure sent by the terminal device, wherein the one-dimensional layer velocity on each measuring line corresponds to a simulated well position; All of the one-dimensional formation pressures are combined to obtain a three-dimensional formation pressure body.

2. The method for determining a three-dimensional formation pressure body according to claim 1, characterized in that: The constructing of a three-dimensional layer velocity model based on the depth domain layer velocity data comprises: Determine the abscissa, ordinate and one-dimensional layer velocity of each survey line in the depth domain layer velocity data; Determine one-dimensional depth data according to the sampling rate of the one-dimensional layer velocity; The three-dimensional layer velocity model is obtained based on the abscissa, the ordinate and the three-dimensional space point corresponding to the one-dimensional depth data of each survey line.

3. The method for determining a three-dimensional formation pressure body according to claim 2, characterized in that: The step of sending the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to a terminal device comprises: Determine a data volume consisting of the abscissa, the ordinate, the one-dimensional layer velocity and the one-dimensional depth data of each survey line; Divide all the data bodies into t data body sets on average; The t data sets are sent to t terminal devices respectively.

4. The method for determining a three-dimensional formation pressure body according to claim 3, characterized in that: Each of the data sets corresponds to at least one of the one-dimensional formation pressures, and merging all of the one-dimensional formation pressures to obtain a three-dimensional formation pressure body includes: The one-dimensional formation pressures corresponding to the data sets are combined to obtain the three-dimensional formation pressure body.

5. A method for determining a three-dimensional formation pressure body, characterized in that: Applied to a system including a host and a terminal device, the method includes: The host obtains depth domain layer velocity data; The host constructs a three-dimensional layer velocity model based on the depth domain layer velocity data; The host sequentially sends the one-dimensional layer velocity on each survey line in the three-dimensional layer velocity model to the terminal device, wherein the one-dimensional layer velocity on each survey line corresponds to a simulated well position; The terminal device determines the one-dimensional formation pressure of the current simulated well position according to the received one-dimensional layer velocity, and sends the one-dimensional formation pressure to the host; The host computer combines all the one-dimensional formation pressures to obtain a three-dimensional formation pressure body.

6. The method for determining a three-dimensional formation pressure body according to claim 5, characterized in that: The terminal device determines the one-dimensional formation pressure of the current simulated well position according to the received one-dimensional layer velocity, including: Determining the overburden pressure of the current simulated well location; Converting the one-dimensional layer velocity into one-dimensional acoustic wave time difference data; Processing the one-dimensional acoustic wave time difference data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data; The one-dimensional formation pressure is obtained based on the overburden pressure, the normal compaction acoustic wave time difference curve, and the one-dimensional acoustic wave time difference data.

7. The method for determining a three-dimensional formation pressure body according to claim 6, characterized in that: The step of processing the one-dimensional acoustic wave time difference data to obtain a normal compaction acoustic wave time difference curve corresponding to the one-dimensional acoustic wave time difference data includes: Based on the Mann-Kendall trend test algorithm, automatically determine the one-dimensional decreasing acoustic wave time difference data corresponding to the longest decreasing segment in the one-dimensional acoustic wave time difference data; Performing data processing on the one-dimensional decreasing sound wave time difference data to obtain a logarithmic value corresponding to the one-dimensional decreasing sound wave time difference data; The logarithmic value of the one-dimensional decreasing acoustic wave time difference data and the one-dimensional depth data are subjected to regression processing to obtain the normal compaction acoustic wave time difference curve.

8. An electronic device, characterized in that: The electronic device comprises: A memory storing a computer program; A processor is communicatively connected to the memory, and executes the three-dimensional formation pressure body determination method according to any one of claims 1 to 7 when calling the computer program.

9. A three-dimensional formation pressure body determination system, characterized in that: The system includes a host and a terminal device, and is used to implement the three-dimensional formation pressure body determination method described in claims 5 to 7.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the three-dimensional formation pressure body determination method according to any one of claims 1 to 7 is implemented.

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