Method and system for quantifying similarity degree of actually-drilled well track and designed well track and storage medium

Abstract

The invention provides a method, a system, a storage medium and equipment for quantifying the similarity degree of actual drilling and designed borehole trajectories. The method comprises the following steps: collecting actual drilling and design well track data of a target well; according to the borehole trajectory data, calculating a deviation degree component of the actually-drilled borehole trajectory relative to a designed borehole trajectory; and based on the deviation degree component, calculating to obtain the trajectory deviation degree. According to the method for quantifying the similarity between the actually-drilled well track and the designed well track, a theoretical basis is provided for evaluating the similarity between the actually-drilled well track and the designed well track, and the evaluation accuracy is improved.

Description

Technical Field

[0001] This invention belongs to the field of petroleum engineering technology, and in particular relates to a method, system, storage medium and equipment for quantifying the similarity between actual drilling and designed wellbore trajectories. Background Technology

[0002] During the drilling process, factors such as formation dip angle, formation build-up, tool error, and operational error can cause the actual drilled wellbore trajectory to not completely correspond to the designed wellbore trajectory. Evaluating the degree of conformity between the actual drilled wellbore trajectory and the designed wellbore trajectory is crucial for the smooth construction of subsequent operations and the evaluation of drilling operation results.

[0003] Currently, the evaluation of the conformity between the actual drilled wellbore trajectory and the designed wellbore trajectory mainly relies on target hitting and whether the target well depth has been reached. However, this evaluation method uses a single evaluation index and fails to quantify the conformity between the actual drilled wellbore trajectory and the designed wellbore trajectory by combining actual drilling directional measurement data. Therefore, it cannot quickly and rationally evaluate the quality of drilling operations based on the quantified results. Consequently, the evaluation accuracy is low. Summary of the Invention

[0004] To address the shortcomings of existing technologies, this invention provides a method, system, storage medium, and device for quantifying the similarity between actual drilled and designed wellbore trajectories. Based on the wellhead, target point, endpoint, and key inclination measurement points, the invention defines and quantifies the concepts of wellhead deviation, target point deviation, endpoint deviation, and deviation of other points to obtain the trajectory offset as a quantitative result of the similarity between actual drilled and designed wellbore trajectories. This provides a theoretical basis for quantitatively evaluating the similarity between actual drilled and designed wellbore trajectories and improves the accuracy of the evaluation.

[0005] This invention is achieved through the following technical solution:

[0006] Collect actual drilling and designed wellbore trajectory data for the target well;

[0007] Based on the wellbore trajectory data, calculate the deviation component of the actual drilled wellbore trajectory relative to the designed wellbore trajectory;

[0008] Based on the deviation component, the trajectory offset is calculated.

[0009] Optional,

[0010] The wellbore trajectory data includes:

[0011] Wellhead location coordinates, endpoint location coordinates, rotary table height, well depth, target point allowable radius, and other measuring point data.

[0012] Optional,

[0013] The deviation component of the actual drilled wellbore trajectory from the designed wellbore trajectory includes:

[0014] Wellhead coordinate deviation, target point deviation, endpoint coordinate deviation, and other total point coordinate deviations.

[0015] Optional,

[0016] The formula for calculating the wellhead coordinate deviation is:

[0017]

[0018] Among them, S h X represents the wellhead coordinate deviation. hD Y hD KB hD These represent the design wellhead's east and north coordinates, as well as the rotary table height, in meters; X hA y hA KB hA These represent the east and north coordinates of the actual drilled wellhead and the height of the rotary table, in meters; H represents the designed maximum well depth of the target well section, in meters.

[0019] Optional,

[0020] The formula for calculating the target deviation is:

[0021]

[0022] Among them, S T r represents the target deviation. D r A These are the maximum allowable target radius and the actual drilled target radius, respectively, in meters (m).

[0023] Optional,

[0024] The deviation of the coordinates of the remaining total points is the average value of the deviation of the coordinates of the remaining measuring points.

[0025] Optional,

[0026] The calculation of trajectory offset based on the deviation component includes:

[0027] The trajectory offset is calculated by summing the deviation components.

[0028] The present invention also provides a system for quantifying the similarity between actual drilling and designed wellbore trajectories, for implementing the aforementioned method, the system comprising:

[0029] The data acquisition module is used to collect actual drilling and designed wellbore trajectory data of the target well;

[0030] The calculation module is used to calculate the deviation component of the actual drilled well trajectory relative to the designed well trajectory based on the well trajectory data.

[0031] A similarity quantification module is used to calculate the trajectory offset based on the deviation component.

[0032] Optional,

[0033] The deviation component of the actual drilled wellbore trajectory from the designed wellbore trajectory includes:

[0034] Wellhead coordinate deviation, target point deviation, endpoint coordinate deviation, and other total point coordinate deviations.

[0035] Optional,

[0036] The calculation module is also configured to calculate the wellhead coordinate deviation, using the following formula:

[0037]

[0038] Among them, S h X represents the wellhead coordinate deviation. hD Y hD KB hD These represent the design wellhead's east and north coordinates, as well as the rotary table height, in meters; X hA Y hA KB hA These represent the east and north coordinates of the actual drilled wellhead and the height of the rotary table, in meters; H represents the designed maximum well depth of the target well section, in meters.

[0039] Optional,

[0040] The calculation module is also configured to calculate the target deviation, using the following formula:

[0041]

[0042] Among them, S T r represents the target deviation. D r A These are the maximum allowable target radius and the actual drilled target radius, respectively, in meters (m).

[0043] Optional,

[0044] The similarity metric module is also configured to:

[0045] The trajectory offset is calculated by summing the deviation components.

[0046] The present invention also provides a computer-readable storage medium storing one or more programs, which, when executed, can realize the aforementioned method for quantifying the similarity between actual drilling and designed wellbore trajectories.

[0047] The present invention also provides a device, including a processor, a communication interface, a computer-readable storage medium, and a communication bus; wherein the processor, the communication interface, and the computer-readable storage medium communicate with each other through the communication bus;

[0048] The processor is used to execute programs stored in a computer-readable storage medium.

[0049] Compared with the prior art, the present invention has the following advantages:

[0050] 1. The quantitative method for the similarity between actual drilled and designed wellbore trajectories proposed in this invention comprehensively considers the wellhead, target point, endpoint, and key inclination measurement points. It defines and quantifies the concepts of wellhead deviation, target point deviation, endpoint deviation, and deviation of other points, and uses the trajectory offset as the quantitative result of the similarity between actual drilled and designed wellbore trajectories. This allows for a comprehensive and scientific evaluation of actual drilled wellbore trajectories, improving the accuracy of evaluating the similarity between actual drilled and designed wellbore trajectories.

[0051] 2. By using drilling survey data, the degree of conformity between the actual drilled wellbore trajectory and the designed wellbore trajectory is quantified, providing a theoretical basis for quantitatively evaluating the similarity between the actual drilled wellbore trajectory and the designed wellbore trajectory. This allows for a rapid and reasonable quantitative evaluation of the conformity between the actual drilled wellbore trajectory on-site, saving evaluation time and improving evaluation efficiency.

[0052] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures pointed out in the description, claims and drawings. Attached Figure Description

[0053] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0054] Figure 1 A flowchart illustrating the method for quantifying the similarity between actual drilling and designed wellbore trajectories is shown.

[0055] Figure 2 A schematic block diagram of the system for quantifying the similarity between actual drilling and designed wellbore trajectories is shown.

[0056] Figure 3 This is a schematic diagram of the structure of a device according to an embodiment of the present invention. Detailed Implementation

[0057] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0058] See appendix Figure 1 The method of the present invention includes:

[0059] S1. Collect actual drilling and design wellbore trajectory data of the target well;

[0060] The wellbore trajectory data includes:

[0061] Wellhead location coordinates, endpoint location coordinates, rotary table height, well depth, target point allowable radius, and other measuring point data.

[0062] S2. Based on the wellbore trajectory data, calculate the deviation component of the actual drilled wellbore trajectory relative to the designed wellbore trajectory;

[0063] The deviation component of the actual drilled wellbore trajectory from the designed wellbore trajectory includes:

[0064] Wellhead coordinate deviation, target point deviation, endpoint coordinate deviation, and other total point coordinate deviations.

[0065] The formula for calculating the wellhead coordinate deviation is as follows:

[0066]

[0067] Among them, S h X represents the wellhead coordinate deviation. hD Y hD KB hD These represent the design wellhead's east and north coordinates, as well as the rotary table height, in meters; X hA Y hA KB hA These represent the east and north coordinates of the actual drilled wellhead and the height of the rotary table, in meters; H represents the designed maximum well depth for the target well section, in meters.

[0068] The formula for calculating the target deviation is as follows:

[0069]

[0070] Among them, S T r represents the target deviation. D r AThese are the maximum allowable target radius (design) and the actual drilled target radius (in meters).

[0071] The deviation of the coordinates of the remaining total points is the average value of the deviation of the coordinates of the remaining measuring points.

[0072] S3. Based on the deviation component, calculate the trajectory offset.

[0073] The trajectory offset is calculated by summing the deviation components.

[0074] Specifically,

[0075] I. Data Collection.

[0076] Collect actual drilled wellbore trajectory data and designed wellbore trajectory data of the target well.

[0077] The wellbore trajectory data includes: wellhead location coordinates, endpoint location coordinates, rotary table height, well depth, target point allowable radius, and other measuring point data.

[0078] II. Calculate the deviation component.

[0079] Based on the wellbore trajectory data, the deviation component of the actual drilled wellbore trajectory relative to the designed wellbore trajectory is calculated.

[0080] The deviation components include: wellhead coordinate deviation, target point deviation, endpoint coordinate deviation, and other total point coordinate deviations.

[0081] 1. Wellhead coordinate deviation.

[0082] The wellhead coordinate deviation represents the degree of deviation between the designed wellhead position and the actual drilled wellhead position. The wellhead coordinate deviation is calculated based on the designed wellhead position coordinates, the actual drilled wellhead position coordinates, the rotary table height, and the well depth.

[0083] Wellhead coordinate deviation is defined as the degree of deviation between the designed wellhead position and the actual drilled wellhead position. The actual drilled wellhead position generally refers to the position of the rotary table. During the actual drilling process, due to factors such as well site construction and measurement deviations, there will be a deviation between the designed wellhead position and the actual drilled wellhead position. The wellhead coordinate deviation is calculated according to formula (1):

[0084]

[0085] Among them, S h X represents the wellhead coordinate deviation. hD Y hD KB hD These represent the design wellhead's east and north coordinates, as well as the rotary table height, in meters; X hA Y hA KBhA These represent the east and north coordinates of the actual drilled wellhead and the height of the rotary table, in meters; H represents the designed maximum well depth of the target well section, in meters.

[0086] In this embodiment, the east and north coordinates of the wellhead are used to represent the location of the wellhead.

[0087] 2. Target deviation.

[0088] The target deviation is the ratio of the actual drilled target radius to the maximum allowable target radius. If there are multiple target points, the average deviation of all target points is taken as the target deviation of the entire trajectory.

[0089] The target deviation is defined as the ratio of the actual drilled target radius to the maximum allowable target radius. If there are multiple targets, the average of all target deviations is taken as the target deviation of the overall trajectory.

[0090] Calculate the target deviation according to formula (2):

[0091]

[0092] Among them, S T r represents the target deviation. D r A These are the maximum allowable target radius and the actual drilled target radius, respectively, in meters (m).

[0093] 3. Deviation of endpoint coordinates.

[0094] The endpoint coordinate deviation is the degree of deviation between the designed endpoint position and the actual drilling endpoint position. The endpoint coordinate deviation is calculated based on the designed endpoint position coordinates, the actual drilling endpoint position coordinates, and the well depth.

[0095] The endpoint coordinate deviation is defined as the degree of deviation between the designed endpoint position and the actual drilling endpoint position. The endpoint coordinate deviation is calculated according to formula (3):

[0096]

[0097] Among them, S N X represents the deviation of the endpoint coordinates. ND Y ND TH ND These represent the design endpoint's east and north coordinates and well depth, in meters; x NA Y NA TH NA These represent the east and north coordinates of the actual drilling endpoint and the well depth, respectively, in meters; H represents the designed maximum well depth of the target well section, in meters.

[0098] 4. Deviation of coordinates of other total points.

[0099] The deviation of the coordinates of the remaining total points is the average of the deviations of the coordinates of the remaining measuring points.

[0100] The remaining measuring points are defined as all measuring points other than the wellhead, endpoint, and target point. In this embodiment, during the drilling process, single-point or multi-point inclination measurement operations are performed on the wellbore trajectory, and multiple measuring points will form a set, which is defined as the remaining measuring points.

[0101] In this embodiment, multiple coordinate systems can be used to describe the wellbore trajectory, such as: east coordinate-north coordinate-depth, or well depth-well inclination-azimuth, etc.

[0102] If the East-North-Depth coordinate system is adopted, it is preferable to use the well depth as the reference to calculate the deviation of the coordinates of the remaining total points. The deviation of the coordinates of the remaining total points is calculated according to formula (4):

[0103]

[0104] Among them, S D S represents the deviation of the coordinates of the remaining total points; Di The remaining single-point coordinate deviation; n is the total number of measuring points;

[0105] H D H A These are the designed well depth and the actual well depth along the drilled well trajectory, respectively, under the same east and north coordinate conditions, in meters; H max The design depth is the maximum depth for the target well section, in meters. In actual calculations, the east and north coordinates of the measuring point should be used as a reference, and the corresponding well depths for the same east and north coordinates should be calculated from the designed wellbore trajectory.

[0106] In the East-North-Depth coordinate system, the deviation of the coordinates of the remaining total points can also be calculated using the East coordinate as the reference, according to formula (4):

[0107]

[0108] in, X D X A These are the designed east coordinates and the east coordinates on the actual drilled wellbore trajectory, respectively, under the same well depth and north coordinate conditions, in meters; X max The design value is the maximum absolute value of the eastern coordinate of the target well section, in meters. In actual calculations, the well depth and northern coordinate at the measuring point should be used as a reference, and the eastern coordinate corresponding to the same well depth and northern coordinate should be calculated from the designed wellbore trajectory.

[0109] In the East-North-Depth coordinate system, the deviation of the coordinates of the remaining total points can also be calculated using the North coordinate as the reference, according to formula (4):

[0110]

[0111] in, Y D Y A These are the designed north coordinates and the north coordinates on the actual drilled wellbore trajectory, respectively, under the same well depth and east coordinate conditions, in meters; Y max The design value is the absolute value of the maximum north coordinate for the target well section, in meters. In actual calculations, the well depth and east coordinate at the measuring point should be used as a reference, and the north coordinate corresponding to the same well depth and east coordinate should be calculated from the designed wellbore trajectory.

[0112] In this embodiment, if a well depth-inclination-azimuth coordinate system is used, the deviation of the coordinates of the remaining total points is calculated according to formula (4):

[0113]

[0114] in, INC D INC A These are the designed well inclination angle and the well inclination angle on the actual drilled well trajectory, respectively, under the same depth and azimuth conditions, in degrees; INC max The maximum well inclination angle is designed for the target well section, in degrees. In actual calculations, the well depth and azimuth at the measuring point should be used as a reference, and the well inclination angle corresponding to the same well depth and azimuth should be calculated inversely from the designed wellbore trajectory.

[0115] III. Calculate the trajectory offset.

[0116] The trajectory offset is calculated based on the deviation components, and the degree of deviation of the actual drilling trajectory from the designed trajectory is determined based on the trajectory offset. All deviation components are summed to obtain the trajectory offset, i.e., trajectory offset S = wellhead coordinate deviation S. h +Target deviation S T +Destination coordinate deviation S N + Deviation of other total points S D .

[0117] The larger the trajectory offset value, the greater the difference between the actual drilling trajectory and the designed trajectory, and the lower the similarity. By calculating the trajectory offset, the similarity between the actual drilled well trajectory and the designed well trajectory can be quantified. Based on the trajectory offset value, a direct and accurate evaluation of the similarity between the actual drilled well trajectory and the designed well trajectory of the target well can be made, allowing for a rational evaluation of the drilling operation quality.

[0118] The quantitative evaluation of the entire well section or any section of the target well can be carried out using the quantification method of the similarity between the actual drilling and the designed wellbore trajectory in this embodiment.

[0119] In this embodiment, directional well XX in oilfield A is used as an example for illustration.

[0120] In Oilfield A, there is a directional well XX with a designed depth of 2000m. The designed wellbore trajectory and the actual drilled wellbore trajectory data are shown in Table 1. There is also a directional well YY with a known trajectory deviation of 0.1. Based on the designed wellbore trajectory and the actual drilled wellbore trajectory data of well XX, the deviation between the actual drilled wellbore trajectory and the designed wellbore trajectory of well XX can be calculated, and then the directional well XX and directional well YY can be quantitatively evaluated.

[0121] Table 1

[0122]

[0123] Based on the parameters in Table 1, the following can be calculated:

[0124] Wellhead coordinate deviation:

[0125]

[0126] End point coordinate deviation:

[0127]

[0128] Target deviation:

[0129]

[0130] Target deviation 2:

[0131]

[0132] Total target deviation:

[0133]

[0134] During the actual drilling of Well XX, 32 points were measured. The measurement coordinate system adopted was the East-North-Well-Depth Coordinate System. The measured wellbore trajectory data is shown in Table 2. The deviation of the remaining total points was calculated based on the well depth.

[0135] Table 2

[0136]

[0137]

[0138] Based on the east and north coordinates of the actual drilling trajectory data in Table 2, and combined with the design trajectory data, the design well depth and single-point coordinate deviation of each measuring point can be calculated. The calculation results are shown in Table 3.

[0139]

[0140]

[0141] Based on the data in Tables 2 and 3, the deviation S of the coordinates of the remaining total points can be calculated. D It is 0.04.

[0142] Calculate the trajectory offset based on the aforementioned deviation components:

[0143] Trajectory offset S = Wellhead coordinate deviation S h +Target deviation S T +Destination coordinate deviation S N + Deviation of other total points S D

[0144] The trajectory offset S = 0.045 + 0.043 + 0.35 + 0.04 = 0.478

[0145] The directional well XX and the directional well YY were quantitatively evaluated based on the trajectory deviation. The trajectory deviations of well YY and well YY were compared. Since the trajectory deviation of well YY was 0.1, the actual drilling trajectory of well YY was more consistent with the design trajectory than that of well XX.

[0146] The present invention will be further described in detail below with reference to the accompanying drawings and specific embodiments.

[0147] See appendix Figure 2 The structure of a system for quantifying the similarity between actual and designed wellbore trajectories for implementing the above method is shown, including a data acquisition module, a calculation module, and a similarity quantification module.

[0148] The data acquisition module is used to collect actual drilling and designed wellbore trajectory data of the target well;

[0149] The calculation module is used to calculate the deviation component of the actual drilled well trajectory relative to the designed well trajectory based on the well trajectory data.

[0150] The similarity quantification module is used to calculate the trajectory offset based on the deviation component.

[0151] Furthermore, embodiments of the present invention also provide a device for quantifying the similarity between actual drilling and designed wellbore trajectories, comprising:

[0152] The data acquisition module is used to collect actual drilling and design wellbore trajectory data of the target well; wherein, the wellbore trajectory data includes: wellhead position coordinates, endpoint position coordinates, rotary table height, well depth, target point allowable radius and other measuring point data.

[0153] The calculation module is used to calculate the deviation components of the actual drilled well trajectory relative to the designed well trajectory based on the well trajectory data; wherein, the deviation components include: wellhead coordinate deviation, target point deviation, endpoint coordinate deviation, and other total point coordinate deviations.

[0154] A similarity quantification module is used to calculate the trajectory offset based on the deviation components, wherein the trajectory offset is calculated by summing the deviation components.

[0155] Based on the same inventive concept, the present invention also provides a computer-readable storage medium storing one or more programs, which, when executed, can realize the aforementioned method for quantifying the similarity between actual drilling and designed wellbore trajectories.

[0156] like Figure 3 As shown in the illustration, this embodiment of the invention also provides a device, including a processor, a communication interface, a memory, and a communication bus. The processor, communication interface, and memory communicate with each other via the communication bus.

[0157] The memory is a computer-readable storage medium used to store one or more programs.

[0158] The processor is configured to execute a program stored in a computer-readable storage medium.

[0159] The computer-readable storage medium may be included in the device / apparatus described in the above embodiments; or it may exist independently and not assembled into the device / apparatus.

[0160] Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for quantifying the similarity between actual drilled and designed wellbore trajectories, characterized in that, include: Collect actual drilling and designed wellbore trajectory data for the target well; Based on the wellbore trajectory data, calculate the deviation component of the actual drilled wellbore trajectory relative to the designed wellbore trajectory; Based on the deviation component, the trajectory offset is calculated.

2. The method according to claim 1, characterized in that, The wellbore trajectory data includes: Wellhead location coordinates, endpoint location coordinates, rotary table height, well depth, target point allowable radius, and other measuring point data.

3. The method according to claim 1, characterized in that, The deviation component of the actual drilled wellbore trajectory from the designed wellbore trajectory includes: Wellhead coordinate deviation, target point deviation, endpoint coordinate deviation, and other total point coordinate deviations.

4. The method according to claim 3, characterized in that, The formula for calculating the wellhead coordinate deviation is: Among them, S h X represents the wellhead coordinate deviation. hD Y hD KB hD These represent the design wellhead's east and north coordinates, as well as the rotary table height, in meters; X hA Y hA KB hA These represent the east and north coordinates of the actual drilled wellhead and the height of the rotary table, in meters; H represents the designed maximum well depth of the target well section, in meters.

5. The method according to claim 3, characterized in that, The formula for calculating the target deviation is: Among them, S T r represents the target deviation. D r A These are the maximum allowable target radius and the actual drilled target radius, respectively, in meters (m).

6. The method according to claim 3, characterized in that, The deviation of the coordinates of the remaining total points is the average value of the deviation of the coordinates of the remaining measuring points.

7. The method according to any one of claims 1-6, characterized in that, The calculation of trajectory offset based on the deviation component includes: The trajectory offset is calculated by summing the deviation components.

8. A system for quantifying the similarity between actual drilled and designed wellbore trajectories, characterized in that, The system includes: The data acquisition module is used to collect actual drilling and designed wellbore trajectory data of the target well; The calculation module is used to calculate the deviation component of the actual drilled well trajectory relative to the designed well trajectory based on the well trajectory data. A similarity quantification module is used to calculate the trajectory offset based on the deviation component.

9. The system according to claim 8, characterized in that, The deviation component of the actual drilled wellbore trajectory from the designed wellbore trajectory includes: Wellhead coordinate deviation, target point deviation, endpoint coordinate deviation, and other total point coordinate deviations.

10. The system according to claim 9, characterized in that, The calculation module is also configured to calculate the wellhead coordinate deviation, using the following formula: Among them, S h X represents the wellhead coordinate deviation. hD Y hD KB hD These represent the design wellhead's east and north coordinates, as well as the rotary table height, in meters; X hA Y hA KB hA These represent the east and north coordinates of the actual drilled wellhead and the height of the rotary table, in meters; H represents the designed maximum well depth of the target well section, in meters.

11. The system according to claim 9, characterized in that, The calculation module is also configured to calculate the target deviation, using the following formula: Among them, S T r represents the target deviation. D r A These are the maximum allowable target radius and the actual drilled target radius, respectively, in meters (m).

12. The system according to any one of claims 8-11, characterized in that, The similarity metric module is also configured to: The trajectory offset is calculated by summing the deviation components.

13. A computer-readable storage medium storing one or more programs, characterized in that, When one or more of these programs are executed, the method for quantifying the similarity between actual drilling and designed wellbore trajectories as described in any one of claims 1-7 can be implemented.

14. An electronic device comprising a processor, a communication interface, a computer-readable storage medium as described in claim 13, and a communication bus; wherein, The processor, communication interface, and computer-readable storage medium communicate electronically with each other via a communication bus; characterized in that, The processor is used to execute programs stored in a computer-readable storage medium.

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