Method, device and medium for determining leakage position of hydrogen transmission pipeline

Abstract

Embodiments of the present application are applicable to the technical field of pipeline detection, and provide a method, device, equipment and medium for determining a leakage position of a hydrogen transmission pipeline. The method comprises: collecting first gas pressures at multiple monitoring positions in a pipeline transporting hydrogen and an initial gas pressure of the hydrogen during transportation of the hydrogen; generating a leakage detection result of the pipeline according to the multiple first gas pressures and a standard gas pressure range corresponding to the pipeline when transporting the initial gas pressure; if the leakage detection result is that the pipeline has leaked, calculating a first pressure difference between each first gas pressure and a corresponding historical first gas pressure; and determining a leakage position of the pipeline according to the multiple first pressure differences. The above method can accurately determine the position of the pipeline where the leakage occurs when the pipeline leaks.

Description

Technical Field

[0001] This application belongs to the field of pipeline inspection technology, and in particular relates to a method, apparatus, equipment and medium for determining the leakage location of a hydrogen transmission pipeline. Background Technology

[0002] During the pipeline transportation of hydrogen, leaks may occur due to factors such as earthquakes, pipeline aging, or corrosion, posing a safety hazard during hydrogen transport. Therefore, it is necessary to test the tightness of the pipelines.

[0003] Currently, the pipeline is usually inspected periodically by staff, or the difference between the hydrogen flow rate in the pipeline and the expected flow rate is measured by a flow meter to determine if it exceeds a preset value.

[0004] However, regular pipeline inspections are labor-intensive and cannot detect leaks in a timely manner. Furthermore, the accuracy of flow meter detection is low for minor leaks. Additionally, when the detected leak difference exceeds a preset threshold, only the flow meter corresponding to that difference can be identified as having a leak; the exact location of the leak cannot be determined. Summary of the Invention

[0005] This application provides a method, apparatus, terminal equipment, and storage medium for determining the location of a leak in a hydrogen transmission pipeline, which can solve the problem of being unable to accurately determine the location of a pipeline leak.

[0006] In a first aspect, embodiments of this application provide a method for determining the location of a leak in a hydrogen transmission pipeline, the method comprising:

[0007] During the transportation of hydrogen, the first gas pressure and the initial gas pressure of hydrogen are collected at multiple monitoring locations in the pipeline transporting hydrogen.

[0008] Based on multiple first gas pressures and the standard gas pressure range corresponding to the pipeline when transporting the initial gas pressure, the pipeline leak detection results are generated.

[0009] If the leak detection result indicates that the pipeline is leaking, then calculate the first pressure difference between each first gas pressure and the corresponding historical first gas pressure.

[0010] The location of the pipeline leak was determined based on multiple initial pressure differences.

[0011] Secondly, embodiments of this application provide a device for determining the leakage location of a hydrogen transmission pipeline, the device comprising:

[0012] The first determining module is used to determine the initial gas pressure of the hydrogen to be transported;

[0013] The data acquisition module is used to collect the first gas pressure at multiple monitoring locations in the pipeline transporting hydrogen during the hydrogen transportation process.

[0014] The generation module is used to generate pipeline leak detection results based on the first gas pressure and the standard gas pressure range corresponding to the pipeline at the initial gas pressure during transportation.

[0015] The second determining module is used to determine the location of the pipeline leak based on multiple first gas pressures and the historical first gas pressure corresponding to each first gas pressure if the leak detection result indicates that the pipeline is leaking.

[0016] Thirdly, embodiments of this application provide a terminal device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the method described in the first aspect above.

[0017] Fourthly, embodiments of this application provide a computer-readable storage medium storing a computer program that, when executed by a processor, implements the method described in the first aspect above.

[0018] Fifthly, embodiments of this application provide a computer program product that, when run on a terminal device, causes the terminal device to execute the method described in the first aspect.

[0019] The beneficial effects of this application embodiment compared to the prior art are as follows: The terminal device can characterize the gas pressure of the entire pipeline during transportation by collecting the first gas pressure at multiple monitoring locations of the pipeline and the initial gas pressure during the initial hydrogen transportation. Since the gas pressure during pipeline transportation is usually related to the initial gas pressure during hydrogen transportation, and when the pipeline is leak-free, other pressures inside the pipeline differ from the gas pressure outside the pipeline, resulting in a pressure difference. Therefore, it can be assumed that when a pipeline leaks, the gas pressure inside the pipeline will change drastically in order to balance the gas pressure inside and outside the pipeline. Based on this, the terminal device can compare the first gas pressure collected at each monitoring location with the standard gas pressure range when the pipeline is transporting hydrogen at the initial gas pressure, generating a pipeline leak detection result. Furthermore, the terminal device can accurately and promptly detect whether a pipeline leak has occurred without incurring significant manpower costs. Simultaneously, the distance between the monitoring location and the leak location typically affects the magnitude of the gas pressure change. Therefore, when the leak detection result indicates that a pipeline leak has occurred, the terminal equipment can also calculate the first pressure difference between each first gas pressure and the corresponding historical first gas pressure, so as to accurately determine the location of the pipeline leak based on the change in gas pressure at each monitoring location, so that staff can determine the location of the pipeline leak in a timely and accurate manner. Attached Figure Description

[0020] To more clearly illustrate the technical solutions in the embodiments of this application, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0021] Figure 1 This is a flowchart illustrating the implementation of a method for determining the leakage location of a hydrogen transmission pipeline according to an embodiment of this application.

[0022] Figure 2 This is a schematic diagram illustrating one implementation of the method for determining the sampling duration in a hydrogen transmission pipeline leakage location determination method provided in an embodiment of this application;

[0023] Figure 3 This is a schematic diagram of a device for determining the leakage location of a hydrogen transmission pipeline according to an embodiment of this application;

[0024] Figure 4 This is a schematic diagram of the structure of a terminal device provided in an embodiment of this application. Detailed Implementation

[0025] In the following description, specific details such as particular system architectures and techniques are set forth for illustrative purposes and not for limitation, in order to provide a thorough understanding of the embodiments of this application. However, those skilled in the art will understand that this application may also be implemented in other embodiments without these specific details. In other instances, detailed descriptions of well-known systems, apparatuses, circuits, and methods have been omitted so as not to obscure the description of this application with unnecessary detail.

[0026] It should be understood that, when used in this application specification and the appended claims, the term "comprising" indicates the presence of the described features, integrals, steps, operations, elements and / or components, but does not exclude the presence or addition of one or more other features, integrals, steps, operations, elements, components and / or a collection thereof.

[0027] Furthermore, in the description of this application and the appended claims, the terms "first," "second," "third," etc., are used only to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0028] During the pipeline transportation of hydrogen, leaks may occur due to factors such as earthquakes, pipeline aging, or corrosion, posing a safety hazard during hydrogen transport. Therefore, it is necessary to test the tightness of the pipelines.

[0029] Currently, pipelines are typically inspected periodically by staff, or a flow meter is used to determine if the difference between the hydrogen flow rate in the pipeline and the expected flow rate exceeds a preset threshold. For example, if the difference is greater than the preset threshold, a pipeline leak can be identified. Otherwise, if the difference is less than or equal to the preset threshold, no leak is identified.

[0030] However, regular pipeline inspections are labor-intensive and cannot detect leaks promptly. Furthermore, even with minor leaks, the difference in flow rate readings may still be less than the preset threshold, resulting in low accuracy for flow meter detection. Moreover, when the difference is greater than the preset threshold, only the flow meter corresponding to that difference indicates a leak, not the specific location of the leak. Consequently, this prevents staff from promptly locating the leak.

[0031] Therefore, in order to ensure the accuracy of pipeline inspection and to accurately and promptly determine the location of pipeline leaks, this embodiment provides a method for detecting hydrogen transport pipelines. This method can be applied to terminal devices such as tablet computers, laptops, Ultra-Mobile Personal Computers (UMPCs), and netbooks. This application embodiment does not impose any restrictions on the specific type of terminal device.

[0032] It should be noted that the detection method for hydrogen transport pipelines provided in this embodiment can also be applied to pipelines transporting other gases, such as pipelines transporting natural gas, and is not limited thereto.

[0033] S101. During the transportation of hydrogen, the first gas pressure and the initial gas pressure of hydrogen are collected at multiple monitoring locations in the pipeline transporting hydrogen.

[0034] In one embodiment, hydrogen is typically transferred between a hydrogen storage device and a hydrogen-using device via pipelines. Since the hydrogen-using devices are usually located in different places, the distribution of each pipeline for transferring hydrogen varies. This distribution of each pipeline forms the pipeline distribution between the storage device and all hydrogen-using devices.

[0035] For example, in a hydrogen refueling station, the locations of the various hydrogen refueling devices are not the same, and storage devices typically transport hydrogen to each refueling device via pipelines.

[0036] It should be noted that the detection method for hydrogen transport pipelines in this embodiment is applied to the detection of each pipeline separately. The detection method for hydrogen transport pipelines described above is performed on each pipeline to generate leakage detection results for each pipeline. That is, when there are multiple pipelines, multiple monitoring locations are determined for each pipeline to be detected.

[0037] In one embodiment, the monitoring location can be set by staff or determined from the pipeline according to preset setting rules, and there is no limitation on this.

[0038] Specifically, the terminal equipment can first determine the distribution of the pipeline, then determine the location of the bends in the pipeline based on the distribution, and then designate each bend location as a monitoring location.

[0039] Understandably, hydrogen is not typically transported directly between storage devices and hydrogen-consuming devices via straight pipelines. Instead, a bend in the pipeline is used to change the direction of the connection between the storage and hydrogen-consuming devices. Therefore, the terminal equipment can determine the location of the bend as the monitoring point.

[0040] It should be noted that for the pipeline between the two bends, since the bends are the monitoring locations, the first gas pressure collected at the two monitoring locations can be used to characterize the pressure change in the pipeline between the two bends.

[0041] In another embodiment, the pipeline distance between the two bends may be relatively long. When hydrogen is transported in a long pipeline, if a leak occurs, the leak detection result obtained by detecting the leak based on the first gas pressure collected at the two bends may be inaccurate. Furthermore, when a leak occurs in the middle region of the pipeline between the two bends, it is usually not possible to generate a leak detection result in a timely manner based on the first gas pressure collected at the two bends.

[0042] Based on this, the terminal device can also determine the pipe distance between two adjacent bends according to the distribution. Then, for any pipe distance, if the pipe distance is greater than a first preset distance, the position corresponding to every second preset distance is determined as the monitoring position.

[0043] It should be noted that the aforementioned adjacent bend positions refer to bends on the same pipeline, and these two bend positions are adjacent. For example, for pipelines A and B, bend position A1 and bend position B1 in pipeline A are not adjacent bend positions. Therefore, it is impossible to identify whether pipelines A and B are leaking based on the first gas pressure at bend positions A1 and B1. Furthermore, if the bend positions along the hydrogen transport direction in pipeline A are A1, A2, and A3 in sequence, then A1 and A2 are two adjacent bend positions, and A2 and A3 are two adjacent bend positions.

[0044] In one embodiment, both the first preset distance and the second preset distance can be set according to actual conditions, and there is no limitation on this.

[0045] It should be noted that for storage devices, this is the starting point of hydrogen transportation, and for hydrogen-using devices, it is the ending point of hydrogen transportation. Therefore, when setting monitoring locations, the starting and ending points can also be used. The hydrogen gas pressure at the starting point is the aforementioned initial gas pressure.

[0046] In one embodiment, the terminal device can determine the initial gas pressure of the hydrogen to be transported and the first gas pressure at each monitoring location using a pressure gauge or pressure sensor; details are not provided here. The initial gas pressure can be any pressure between 0 MPa and 70 MPa, and is not limited thereto.

[0047] The terminal device can collect the initial gas pressure and the first gas pressure in real time or at preset intervals to determine the leak detection results.

[0048] It should be noted that since the pressure of gas during pipeline transportation is usually related to the initial gas pressure during hydrogen transportation, when the initial gas pressure of the hydrogen to be transported changes, a certain amount of time needs to be waited before the first gas pressure can be collected in order to accurately generate leak detection results.

[0049] Understandably, when the initial gas pressure remains unchanged, the pressures of various gases within the pipeline are usually unaffected. However, when the initial gas pressure changes, because each monitoring location is some distance from the starting location, it takes a certain amount of time for the hydrogen gas corresponding to the initial gas pressure to reach the monitoring location. Therefore, if the initial gas pressure is collected at each monitoring location simultaneously with the change in initial gas pressure, the accuracy of the leak detection results generated based on the standard gas pressure range corresponding to the collected initial gas pressure and the current initial gas pressure may be low.

[0050] Based on this, when the initial gas pressure is consistent with the historical gas pressure for transporting hydrogen at a given time, the terminal device can collect the first gas pressure at each monitoring location at preset intervals. Otherwise, when the initial gas pressure is inconsistent with the historical gas pressure for transporting hydrogen at a given time, the terminal device can determine the collection duration for each monitoring location separately and collect the first gas pressure at intervals.

[0051] The aforementioned historical moment can be the moment of the initial gas pressure of the hydrogen to be transported last time it was collected. Furthermore, the aforementioned preset duration can be set according to actual circumstances and is not limited thereto.

[0052] It should be noted that if the pressure difference between the initial gas pressure and the historical gas pressure is less than the preset pressure difference, the initial gas pressure can be considered unchanged (i.e., the initial gas pressure is consistent with the historical gas pressure). Otherwise, if the pressure difference between the initial gas pressure and the historical gas pressure is greater than or equal to the preset pressure difference, the initial gas pressure can be considered changed (i.e., the initial gas pressure is consistent with the historical gas pressure).

[0053] The preset pressure difference can be set according to the actual situation, and there is no limitation on it.

[0054] In one embodiment, the terminal device may pre-store the correlation between gas pressure, monitoring location, and data acquisition duration. Then, the terminal device can directly determine the data acquisition duration corresponding to each monitoring location at the current initial gas pressure based on this correlation.

[0055] As an example, the terminal device can be based on, for example... Figure 2 S201-S205, as shown, determine the data acquisition duration for each monitoring location. Details are as follows:

[0056] S201. For any monitoring location, collect the second gas pressure corresponding to the monitoring location.

[0057] S202. Calculate the second pressure difference between the second gas pressure and the initial gas pressure.

[0058] In one embodiment, the second gas pressure is the gas pressure synchronously collected when a change in the initial gas pressure is detected. When the second pressure difference is negative, its absolute value is used in subsequent processing.

[0059] S203. Determine the first target pipeline between the monitoring location and the starting point of hydrogen transportation.

[0060] In one embodiment, the first target pipes between different monitoring positions and the starting position are typically different, resulting in different pipe parameters for the target pipes between different monitoring positions and the starting position. For example, the lengths of the first target pipes are typically different. Furthermore, within a single pipe, the target pipes between a distant monitoring position and the starting position include not only the first target pipes between a nearby monitoring position and the starting position, but also the first target pipes between distant and nearby monitoring positions.

[0061] Specifically, for monitoring positions A1 and A2 in pipeline A, if the distance between monitoring position A2 and the starting position A0 is greater than the distance between monitoring position A1 and the starting position A0 (i.e., along the hydrogen transport direction, hydrogen first arrives at monitoring position A1 in the pipeline, and then arrives at monitoring position A2), then the first target pipeline between A2 and A0 includes not only the first target pipeline between A1 and A0, but also the first target pipeline between A1 and A2.

[0062] S204. Based on the pipeline parameters of the first target pipeline and the second pressure difference, determine the transportation time of hydrogen from the starting position to the monitoring position.

[0063] In one embodiment, as can be seen from the above, different monitoring locations include different target pipes, and therefore, the pipe parameters of the corresponding first target pipes are usually different.

[0064] The pipeline parameters include, but are not limited to, the length of the first pipeline, the inner diameter of the pipeline, and the roughness of the inner wall, etc.

[0065] It should be noted that the inner diameter and inner wall roughness of a pipeline may vary at different monitoring locations. In this case, the inner diameter can be pre-measured and set by personnel. However, the inner wall roughness is usually affected by time and environment and cannot be determined in real time. Therefore, when determining the inner wall roughness, the product of the initial inner wall roughness and the weight corresponding to the pipeline's usage time can be used as the inner wall roughness. In this embodiment, the same value is used for the inner wall roughness of the target pipeline at each monitoring location in subsequent processing.

[0066] The weights corresponding to the aforementioned durations can be preset and are not subject to any restrictions. It should be noted that the weights must be values ​​greater than 1.

[0067] In one specific embodiment, the terminal device can input pipeline parameters and pressure difference into a preset time calculation formula to obtain the transportation time; the time calculation formula is as follows:

[0068]

[0069] Where T is the transportation time, l is the length of the first target pipeline, d is the inner diameter of the first target pipeline, P is the second pressure difference, ρ is the density of hydrogen, A is a constant, and n is the roughness of the inner wall of the first target pipeline.

[0070] The constant A mentioned above can be set by the staff. For example, the constant A can be 10.

[0071] It should be noted that the transportation time is typically calculated by dividing the pipeline length (distance) by the speed. In this embodiment, the speed of hydrogen is determined by the flow rate of hydrogen passing through the monitoring location. In the above formula, Characterizes the frictional resistance encountered by hydrogen gas during pipeline transportation; The gas flow rate of hydrogen at the monitoring position is characterized when the pressure difference between the starting position and the monitoring position is the aforementioned second pressure difference P. This characterizes the flow velocity of hydrogen as it passes the monitoring location. Based on this, the length l of the first pipe is divided by this flow velocity. The resulting formula is the same as the above formula for calculating duration.

[0072] S205. The transportation time is determined as the data collection time.

[0073] In one embodiment, after determining the transportation time, it can be assumed that when the hydrogen gas pressure is the initial gas pressure, the hydrogen will affect the gas pressure at the monitoring location after the transportation time. Therefore, the transportation time can be determined as the data collection time, so that the first gas pressure at the corresponding monitoring location can be collected after the data collection time, thereby improving the accuracy of the collected first gas pressure.

[0074] S102. Generate pipeline leak detection results based on multiple first gas pressures and the standard gas pressure range corresponding to the pipeline when the initial gas pressure is being transported.

[0075] In one embodiment, when hydrogen is transported in a pipeline, the gas pressure at various monitoring locations may fluctuate normally due to the accuracy of the gas pressure acquisition equipment or the influence of the external environment during transportation. Typically, the amplitude of this fluctuation is small.

[0076] Based on this, the terminal device can pre-store the standard gas pressure range corresponding to each initial gas pressure. Then, if multiple first gas pressures are within the standard gas pressure range, the terminal device can determine that the leak detection result is that the pipeline is not leaking; and if any first gas pressure is not within the standard gas pressure range, the terminal device can determine that the leak detection result is that the pipeline is leaking.

[0077] In another embodiment, the gas pressure at different monitoring locations typically differs as the gas flows within the pipeline. Specifically, along the hydrogen transport direction, the gas pressure at upstream monitoring locations is generally higher than that at downstream monitoring locations. Therefore, the standard gas pressure range corresponding to each monitoring location can also be different. That is, when determining the standard gas pressure range, it can also be determined simultaneously based on the initial gas pressure and the monitoring location, without limitation.

[0078] Understandably, when a pipeline leaks, the gas pressure inside the pipeline will change drastically to balance the pressure inside and outside. Specifically, when a pipeline leaks, the gas pressure inside the pipeline will typically decrease to balance the pressure inside and outside. Therefore, a pipeline leak can be determined when any initial gas pressure is less than the minimum value of the standard gas pressure range.

[0079] S103. If the leak detection result indicates that the pipeline is leaking, calculate the first pressure difference between each first gas pressure and the corresponding historical first gas pressure.

[0080] In one embodiment, the terminal device can store the first gas pressure at each monitoring location collected each time, so that when the method for determining the leak location of the hydrogen transmission pipeline is executed at the next moment, the historical first gas pressure corresponding to each first gas pressure can be directly determined.

[0081] S104. Determine the location of the pipeline leak based on multiple first pressure differences.

[0082] In one embodiment, the first pressure difference can be used to characterize the magnitude of air pressure change from a historical time to the current time at the monitoring location. The terminal device can input multiple first pressure differences into a pre-trained leak location prediction model to determine the leak location in the pipeline.

[0083] Understandably, when a pipeline leaks, the gas pressure inside will change drastically. That is, the magnitude of the change is usually large. Furthermore, in a pipeline, the gas flow velocity between the first and second monitoring points is typically similar. Therefore, given similar gas flow velocities, the pressure change closer to the leak will be greater than the pressure change farther from the leak.

[0084] It should be added that, for pipelines transporting gases, when a leak occurs in the pipeline, the gas pressure at each monitoring point inside the pipeline can be considered to change linearly.

[0085] Based on this, as an example, the terminal device can first determine the largest first maximum value from multiple first pressure differences, and a second maximum value that is less than the first maximum value but greater than the other first pressure differences. Then, the leak location is determined based on the first maximum value and the second maximum value.

[0086] Specifically, the terminal device can first calculate the ratio of the second maximum value to the sum of the first and second maximum values. Then, it determines the length of the second target pipeline between the first monitoring position corresponding to the first maximum value and the second monitoring position corresponding to the second maximum value. Finally, based on the product of the ratio and the second pipeline length, the leak location is determined; the product is the distance between the first monitoring position and the leak location.

[0087] Among them, the first maximum value is the maximum value among multiple first pressure differences, and the second maximum value is the maximum value among multiple first pressure differences other than the first maximum value.

[0088] In summary, after determining the first and second maximum values, it can be determined that the leak location lies between the first monitoring position corresponding to the first maximum value and the second monitoring position corresponding to the second maximum value, with the leak location being closer to the first monitoring position. Furthermore, since the gas pressure at each monitoring position within the pipeline typically changes linearly when a leak occurs, the terminal equipment can consider the product of the ratio and the length of the second pipeline as the distance between the first monitoring position and the leak location.

[0089] For example, when the first maximum value is 8, the second maximum value is 2, and the length of the second pipeline is 5m, the ratio is 0.2, and the product of the ratio and the length of the second pipeline is 1. That is, the distance between the leak point and the first monitoring point is 1m, and the distance between the leak point and the second monitoring point is 4m, so that the pressure change at the first monitoring point is greater than the pressure change at the second monitoring point.

[0090] It should be noted that, along the direction of hydrogen transport, the gas pressure at upstream monitoring locations within the pipeline is typically higher than that at downstream monitoring locations. That is, even if no leak has occurred in the pipeline, the initial gas pressure at each monitoring location within the pipeline is usually different. Therefore, if, when a leak detection result indicates a pipeline leak, the monitoring location corresponding to the minimum of multiple initial gas pressures is directly determined as the leak location, the located pipeline leak will generally be inaccurate.

[0091] Based on this, in this embodiment, the location of the pipeline leak is determined by using a first pressure difference that characterizes the magnitude of the gas pressure change. This not only allows for the rapid determination of the pipeline leak location but also enables accurate determination of the pipeline leak location.

[0092] In this embodiment, the terminal device can characterize the gas pressure of the entire pipeline during transportation by collecting the first gas pressure at multiple monitoring locations along the pipeline and the initial gas pressure during the initial hydrogen transportation. Since the gas pressure during pipeline transportation is typically related to the initial gas pressure during hydrogen transportation, and when the pipeline is leak-free, the pressures inside and outside the pipeline differ, creating a pressure difference. Therefore, it can be assumed that when a pipeline leaks, the gas pressure inside the pipeline will change drastically to balance the pressures inside and outside the pipeline. Based on this, the terminal device can compare the first gas pressure collected at each monitoring location with the standard gas pressure range of the pipeline when transporting hydrogen at its initial gas pressure, generating a pipeline leak detection result. Thus, the terminal device can accurately and promptly detect pipeline leaks without incurring significant manpower costs. Furthermore, the distance between the monitoring location and the leak location typically affects the magnitude of the gas pressure change. Therefore, when the leak detection result indicates that a pipeline leak has occurred, the terminal equipment can also calculate the first pressure difference between each first gas pressure and the corresponding historical first gas pressure, so as to accurately determine the location of the pipeline leak based on the change in gas pressure at each monitoring location, so that staff can determine the location of the pipeline leak in a timely and accurate manner.

[0093] Please see Figure 3 , Figure 3 This is a schematic diagram of a device for determining the leak location of a hydrogen transmission pipeline according to an embodiment of this application. The modules included in the device for determining the leak location of a hydrogen transmission pipeline in this embodiment are used to perform... Figure 1 and Figure 2 The steps in the corresponding embodiments. Please refer to the details. Figure 1 and Figure 2 as well as Figure 1 and Figure 2 The relevant descriptions in the corresponding embodiments are shown below. For ease of explanation, only the parts relevant to this embodiment are shown. See also... Figure 3 The hydrogen transmission pipeline leak location determination device 300 may include: a first determination module 310, a data acquisition module 320, a generation module 330, and a second determination module 340, wherein:

[0094] The first determining module 310 is used to determine the initial gas pressure of the hydrogen to be transported.

[0095] The acquisition module 320 is used to acquire the first gas pressure at multiple monitoring locations in the pipeline transporting hydrogen during the hydrogen transportation process.

[0096] The generation module 330 is used to generate pipeline leakage detection results based on the first gas pressure and the standard gas pressure range corresponding to the pipeline at the initial gas pressure during transportation.

[0097] The second determining module 340 is used to determine the location of the pipeline leak based on multiple first gas pressures and the historical first gas pressure corresponding to each first gas pressure if the leak detection result indicates that the pipeline is leaking.

[0098] In one embodiment, the acquisition module 320 is further configured to:

[0099] If the initial gas pressure is consistent with the historical initial gas pressure for transporting hydrogen at a historical time, the first gas pressure at each monitoring location is collected at preset intervals; if the initial gas pressure is inconsistent with the historical initial gas pressure for transporting hydrogen at a historical time, the collection time corresponding to each monitoring location is determined, and the first gas pressure is collected at intervals.

[0100] In one embodiment, the acquisition module 320 is further configured to:

[0101] For any monitoring location, the second gas pressure corresponding to the monitoring location is collected; the second pressure difference between the second gas pressure and the initial gas pressure is calculated; the first target pipeline between the monitoring location and the starting point of hydrogen transportation is determined; based on the pipeline parameters of the first target pipeline and the second pressure difference, the transportation time of hydrogen from the starting point to the monitoring location is determined; and the transportation time is determined as the collection time.

[0102] In one embodiment, the acquisition module 320 is further configured to:

[0103] Input the pipeline parameters and the second pressure difference into the preset time calculation formula to obtain the transportation time; the time calculation formula is as follows:

[0104]

[0105] Where T is the transportation time, l is the length of the first target pipeline, d is the inner diameter of the first target pipeline, P is the second pressure difference, ρ is the density of hydrogen, A is a constant, and n is the roughness of the inner wall of the first target pipeline.

[0106] In one embodiment, the generation module 330 is further configured to:

[0107] If multiple first gas pressures are within the standard gas pressure range, the leak detection result is determined to be that the pipeline is not leaking; if any one of the first gas pressures is outside the standard gas pressure range, the leak detection result is determined to be that the pipeline is leaking.

[0108] In one embodiment, the second determining module 340 is further configured to:

[0109] From multiple first pressure differences, determine the largest first maximum value and the second maximum value which is less than the first maximum value but greater than the other first pressure differences; determine the leak location based on the first maximum value and the second maximum value.

[0110] In one embodiment, the second determining module 340 is further configured to:

[0111] Calculate the ratio of the second maximum value to the sum of the first and second maximum values; determine the length of the second target pipeline between the first monitoring position corresponding to the first maximum value and the second monitoring position corresponding to the second maximum value; determine the leak location based on the product of the ratio and the length of the second pipeline; the product is the distance between the first monitoring position and the leak location.

[0112] When it is understood that, Figure 3 In the structural schematic diagram showing the determination of the leak location in the hydrogen transmission pipeline, each module is used to perform... Figure 1 and Figure 2 The steps in the corresponding embodiments, and for Figure 1 and Figure 2 The steps in the corresponding embodiments have been explained in detail in the above embodiments. Please refer to them for details. Figure 1 and Figure 2 as well as Figure 1 and Figure 2 The relevant descriptions in the corresponding embodiments will not be repeated here.

[0113] Figure 4 This is a schematic diagram of the structure of a terminal device provided in one embodiment of this application. For example... Figure 4 As shown, the terminal device 400 of this embodiment includes a processor 410, a memory 420, and a computer program 430 stored in the memory 420 and executable by the processor 410, such as a program for determining the leak location of a hydrogen transmission pipeline. When the processor 410 executes the computer program 430, it implements the steps in the various embodiments of the hydrogen transmission pipeline leak location determination method described above, for example... Figure 1 S101 to S104 are shown. Alternatively, the processor 410 implements the above when executing the computer program 430. Figure 3 The functions of each module in the corresponding embodiments, for example, Figure 3 For details on the functions of each module shown, please refer to [link / reference]. Figure 3 The relevant descriptions in the corresponding embodiments.

[0114] For example, the computer program 430 can be divided into one or more modules, one or more of which are stored in the memory 420 and executed by the processor 410 to implement the method for determining the leak location of a hydrogen transmission pipeline provided in this embodiment. One or more modules can be a series of computer program instruction segments capable of performing specific functions, which describe the execution process of the computer program 430 in the terminal device 400. For example, the computer program 430 can implement the method for determining the leak location of a hydrogen transmission pipeline provided in this embodiment.

[0115] Terminal device 400 may include, but is not limited to, processor 410 and memory 420. Those skilled in the art will understand that... Figure 4 This is merely an example of terminal device 400 and does not constitute a limitation on terminal device 400. It may include more or fewer components than shown, or combine certain components, or different components. For example, terminal device may also include input / output devices, network access devices, buses, etc.

[0116] The processor 410 may be a central processing unit, or it may be other general-purpose processors, digital signal processors, application-specific integrated circuits, off-the-shelf programmable gate arrays or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor may be a microprocessor or any conventional processor, etc.

[0117] The memory 420 can be an internal storage unit of the terminal device 400, such as a hard disk or memory of the terminal device 400. The memory 420 can also be an external storage device of the terminal device 400, such as a plug-in hard disk, smart memory card, flash memory card, etc., equipped on the terminal device 400. Furthermore, the memory 420 can include both internal storage units and external storage devices of the terminal device 400.

[0118] This application provides a computer-readable storage medium storing a computer program, which is executed by a processor using the method for determining the leak location of a hydrogen transmission pipeline in the above embodiments.

[0119] This application provides a computer program product that, when run on a terminal device, causes the terminal device to execute the method for determining the leak location of the hydrogen transmission pipeline in the above embodiments.

[0120] The above embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application 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. Such 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 this application, and should all be included within the protection scope of this application.

Claims

1. A method for determining a leakage position of a hydrogen gas transmission pipeline, characterized by, The method comprises: collecting first gas pressures at multiple monitoring positions in a pipeline transporting the hydrogen during transportation of the hydrogen, and collecting an initial gas pressure of the hydrogen; generating a leakage detection result of the pipeline according to multiple first gas pressures and a standard gas pressure range corresponding to the pipeline when transporting the initial gas pressure; if the leakage detection result is that the pipeline leaks, calculating a first pressure difference between each first gas pressure and a corresponding historical first gas pressure; determining a leakage position of the pipeline according to multiple first pressure differences; the collecting first gas pressures at multiple monitoring positions in a pipeline transporting the hydrogen during transportation of the hydrogen comprises: if the initial gas pressure is consistent with a historical initial gas pressure of the hydrogen at a historical time, collecting a first gas pressure at each monitoring position every preset time interval; if the initial gas pressure is inconsistent with the historical initial gas pressure of the hydrogen at the historical time, determining a collection time interval corresponding to each monitoring position, and collecting the first gas pressure at the collection time interval; if the initial gas pressure is inconsistent with the historical initial gas pressure of the hydrogen at the historical time, determining a collection time interval corresponding to each monitoring position comprises: collecting a second gas pressure corresponding to the monitoring position for any monitoring position; calculating a second pressure difference between the second gas pressure and the initial gas pressure; determining a first target pipeline between the monitoring position and a starting position of the hydrogen in the pipeline transportation; determining a transportation time of the hydrogen from the starting position to the monitoring position according to a pipeline parameter of the first target pipeline and the second pressure difference; determining the transportation time as the collection time interval; determining the transportation time of the hydrogen from the starting position to the monitoring position according to the pipeline parameter of the first target pipeline and the second pressure difference comprises: inputting the pipeline parameter and the second pressure difference into a preset time calculation formula to obtain the transportation time; the time calculation formula is as follows: ； wherein T is the transportation time length, I is a first pipe length of the first target pipe, d is a pipe inner diameter of the first target pipe, P is the second pressure difference, is a density of the hydrogen, A is a constant, and n is an inner wall roughness of the first target pipe.

2. The method of claim 1, wherein, generating a leakage detection result of the pipeline according to multiple first gas pressures and a standard gas pressure range corresponding to the pipeline when transporting the initial gas pressure comprises: if multiple first gas pressures are all in the standard gas pressure range, determining that the leakage detection result is that the pipeline does not leak; if any first gas pressure is not in the standard gas pressure range, determining that the leakage detection result is that the pipeline leaks.

3. The method according to claim 1 or 2, characterized in that, determining a leakage position of the pipeline according to multiple first pressure differences comprises: from multiple first pressure differences, determining a first maximum value with the largest value, and a second maximum value smaller than the first maximum value and larger than other first pressure differences; determining the leakage position according to the first maximum value and the second maximum value.

4. The method of claim 3, wherein, determining the leakage position according to the first maximum value and the second maximum value comprises: a ratio of the second maximum value to a sum of the first maximum value and the second maximum value; determining a second pipe length of a second target pipe between a first monitoring position corresponding to the first maximum value and a second monitoring position corresponding to the second maximum value; determining the leakage position according to a product of the ratio and the second pipe length; the product being a distance between the first monitoring position and the leakage position.

5. A hydrogen gas transmission pipeline leak location determination apparatus characterized by, The device comprises: a first determining module configured to determine an initial gas pressure of hydrogen to be transported; a collecting module configured to collect first gas pressures at a plurality of monitoring positions in a pipe transporting the hydrogen during transportation of the hydrogen; a generating module configured to generate a leakage detection result of the pipe according to the first gas pressures and a standard gas pressure range corresponding to the pipe when transporting the initial gas pressure; a second determining module configured to determine a leakage position of the pipe according to the first gas pressures and historical first gas pressures corresponding to each of the first gas pressures, if the leakage detection result indicates that the pipe has a leakage; The collecting module is further configured to: collect the first gas pressure at each of the monitoring positions every preset time interval, if the initial gas pressure is consistent with a historical initial gas pressure of the hydrogen transported at a historical time; determine a collection time interval corresponding to each of the monitoring positions, and collect the first gas pressure at each of the monitoring positions at the collection time interval, if the initial gas pressure is inconsistent with the historical initial gas pressure of the hydrogen transported at the historical time; The collecting module is further configured to: collect a second gas pressure corresponding to any of the monitoring positions; calculate a second pressure difference between the second gas pressure and the initial gas pressure; determine a first target pipe between the monitoring position and a starting position of the hydrogen in the pipe transportation; determine a transportation time of the hydrogen from the starting position to the monitoring position according to a pipe parameter of the first target pipe and the second pressure difference; determine the transportation time as the collection time interval; The collecting module is further configured to: input the pipe parameter and the second pressure difference into a preset time calculation formula to obtain the transportation time; the time calculation formula is as follows: ； wherein T is the transportation time length, I is a first pipe length of the first target pipe, d is a pipe inner diameter of the first target pipe, P is the second pressure difference, is a density of the hydrogen, A is a constant, and n is an inner wall roughness of the first target pipe.

6. A terminal device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, The processor implements the method of any one of claims 1 to 4 when executing the computer program.

7. A computer-readable storage medium storing a computer program, wherein the computer program comprises the following steps of: receiving a request for a resource from a client; determining whether the client is authorized to access the resource; and if the client is authorized to access the resource, providing the resource to the client. The computer program implements the method of any one of claims 1 to 4 when executed by a processor.

Images