Failure pressure determination method, device and storage medium

Abstract

This application discloses a method, apparatus, and storage medium for determining failure pressure, relating to the field of oil and gas pipeline safety technology. It can accurately calculate the failure pressure of hydrogen-blended natural gas pipelines containing corrosion defects, providing strong technical support for the safe maintenance of such pipelines. The method includes: acquiring the mechanical properties, structural information, size information of corrosion defects on the hydrogen-blended pipeline, and clock angles, where the clock angles characterize the circumferential position of the corrosion defects on the pipeline; modeling the hydrogen-blended pipeline based on the mechanical properties, structural information, size information of the corrosion defects, and clock angles to obtain a model of the hydrogen-blended pipeline containing corrosion defects; and determining the failure pressure of the model of the hydrogen-blended pipeline containing corrosion defects based on the mechanical properties and structural information. The failure pressure is the pressure value of the hydrogen-blended pipeline under conditions of leakage, rupture, or other failures when subjected to internal pressure.

Description

Technical Field

[0001] This application relates to the field of oil and gas pipeline safety technology, and in particular to a method, apparatus and storage medium for determining failure pressure. Background Technology

[0002] As critical infrastructure for the long-distance transportation of oil and natural gas, oil and gas pipelines are essential for the stable operation of the entire energy supply chain. Therefore, accurately calculating the failure pressure of pipelines with corrosion defects is of great significance for ensuring the safe and stable operation of oil and gas pipelines.

[0003] Currently, failure pressure assessments for pipelines with corrosion defects largely rely on empirical formulas. While this method is convenient, it can lead to overly conservative assessment results, causing discrepancies between the estimated and actual failure pressures. Furthermore, pipeline inspections typically uncover numerous corrosion defects. Assessing failure pressures only for pipelines with single or few corrosion defects not only fails to reflect the complexities of engineering practice but also results in low computational efficiency.

[0004] However, current methods for accurately and efficiently calculating the failure pressure of pipelines with numerous and complex corrosion defects remain scarce. Therefore, how to accurately calculate the failure pressure of pipelines with numerous and complex corrosion defects has become an urgent technical problem to be solved. Summary of the Invention

[0005] The purpose of this application is to provide a method, apparatus and storage medium for determining failure pressure, which can accurately calculate the failure pressure of hydrogen-blended natural gas pipelines with corrosion defects, and provide strong technical support for the safe maintenance of hydrogen-blended natural gas pipelines.

[0006] To achieve the above objectives, this application adopts the following technical solution:

[0007] Firstly, this application provides a method for determining failure pressure. The method includes: acquiring mechanical property information, structural information, size information of corrosion defects on the hydrogen-doped pipeline, and clock angles, where the clock angles characterize the circumferential positions of the corrosion defects on the hydrogen-doped pipeline. Then, based on the mechanical property information, structural information, size information of the corrosion defects, and clock angles, a model of the hydrogen-doped pipeline containing corrosion defects is obtained. Finally, based on the mechanical property information and structural information, the failure pressure of the hydrogen-doped pipeline model containing corrosion defects is determined. The failure pressure is the pressure value of the hydrogen-doped pipeline under conditions of leakage, rupture, or other failures when subjected to internal pressure.

[0008] Based on the above technical solution, this application can accurately model a hydrogen-doped pipeline using its mechanical properties, structural information, corrosion defect size information, and clock angle, thereby highly reproducing the actual state of the hydrogen-doped pipeline and providing support for subsequent calculations of its failure pressure. Subsequently, based on the mechanical properties and structural information, the failure pressure of the hydrogen-doped pipeline model containing corrosion defects can be quickly calculated. This provides strong technical support for the safe maintenance of hydrogen-doped pipelines and can effectively prevent pipeline rupture, leakage, and other failure problems.

[0009] In some embodiments, mechanical property information may include the tensile strength of the hydrogen-doped pipeline, and structural information may include the pipeline diameter and wall thickness. Based on this, and using the mechanical and structural information, the failure pressure of the hydrogen-doped pipeline model with corrosion defects is determined. Specifically, this may include determining the maximum permissible pressure for safe operation of the hydrogen-doped pipeline based on its tensile strength, diameter, and wall thickness. Then, using the finite element method, the Mises stress of the hydrogen-doped pipeline model with corrosion defects is determined. The Mises stress is used to assess whether the hydrogen-doped pipeline fails under stress. Finally, based on the maximum permissible pressure and the Mises stress, the failure pressure of the hydrogen-doped pipeline model with corrosion defects is determined.

[0010] In some embodiments, there are multiple Mises stresses, and the failure pressure satisfies the following formula:

[0011]

[0012] Where, σ u The tensile strength of the hydrogen-doped pipeline is given by σ1, where σ1 is the most significant of the multiple Mises stresses less than σ. u The maximum Mises stress, σ2 is the highest Mises stress among multiple Mises stresses that is greater than σ. u The minimum stress of the millisiesselin stress, t1 is the load substep number corresponding to σ1, t2 is the load substep number corresponding to σ2, P max This is the maximum permissible pressure.

[0013] In some embodiments, the maximum permissible pressure satisfies the following formula:

[0014]

[0015] Where, σ u Where is the tensile strength of the hydrogen-doped pipe, D is the pipe diameter, t is the wall thickness, and P is the tensile strength of the hydrogen-doped pipe. max This is the maximum permissible pressure.

[0016] In some embodiments, a hydrogen-doped pipeline is modeled based on mechanical property information, structural information, corrosion defect size information, and clock angle to obtain a hydrogen-doped pipeline model containing corrosion defects. Specifically, this may include: determining the location of corrosion defects on the hydrogen-doped pipeline based on the size information and clock angle of the corrosion defects; then determining the length of the hydrogen-doped pipeline model containing corrosion defects based on the location of the corrosion defects on the hydrogen-doped pipeline; finally, the hydrogen-doped pipeline is modeled based on the mechanical property information, structural information, corrosion defect size information, the length of the hydrogen-doped pipeline model containing corrosion defects, and the location of the corrosion defects on the hydrogen-doped pipeline to obtain a hydrogen-doped pipeline model containing corrosion defects.

[0017] In some embodiments, the hydrogen-infused pipeline is a bend, and the corrosion defect is located at the bend. Based on this, the hydrogen-infused pipeline is modeled using mechanical property information, structural information, corrosion defect size information, the length of the model containing the corrosion defect, and the location of the corrosion defect on the hydrogen-infused pipeline. This model can specifically include: modeling the hydrogen-infused pipeline using mechanical property information, structural information, corrosion defect size information, the length of the model containing the corrosion defect, and the location of the corrosion defect on the hydrogen-infused pipeline to obtain a planar model of the hydrogen-infused pipeline with corrosion defects. Then, the planar model of the hydrogen-infused pipeline with corrosion defects is converted into a straight model of the hydrogen-infused pipeline with corrosion defects. Finally, the straight model of the hydrogen-infused pipeline with corrosion defects is converted into a bend model of the hydrogen-infused pipeline with corrosion defects.

[0018] In some embodiments, the structural information includes the pipe radius and pipe bend radius of the hydrogen-doped pipeline, and the size information of the corrosion defects includes the length of the corrosion defects on the hydrogen-doped pipeline. Based on this, the length of the corrosion defect model in the planar model of the hydrogen-doped pipeline containing corrosion defects is determined as follows: a length scaling factor is determined based on the pipe radius, pipe bend radius, and clock angle; this length scaling factor is used to determine the length of the corrosion defect model. Then, based on the length scaling factor and the length of the corrosion defects, the length of the corrosion defect model is determined; the corrosion defect model is obtained by modeling the corrosion defects on the hydrogen-doped pipeline.

[0019] Secondly, this application provides a failure pressure determination device, comprising:

[0020] The acquisition unit is used to acquire mechanical property information, structural information, size information of corrosion defects on the hydrogen-doped pipeline, and clock angle. The clock angle is used to characterize the circumferential position of corrosion defects on the hydrogen-doped pipeline.

[0021] The processing unit is used to model the hydrogen-doped pipeline based on mechanical property information, structural information, corrosion defect size information, and clock angle to obtain a hydrogen-doped pipeline model containing corrosion defects.

[0022] The determination element is used to determine the failure pressure of a hydrogen-doped pipeline model containing corrosion defects based on mechanical and structural information. The failure pressure is the pressure value of the hydrogen-doped pipeline under conditions of leakage, rupture, or other failures when subjected to internal pressure.

[0023] In some embodiments, the determining unit is further configured to determine the maximum permissible pressure for safe operation of the hydrogen-doped pipeline based on the tensile strength, diameter, and wall thickness of the hydrogen-doped pipeline.

[0024] In some embodiments, the determining unit is also used to determine the Mises stress of a hydrogen-doped pipe model containing corrosion defects using the finite element method.

[0025] In some embodiments, the determining unit is further configured to determine the failure pressure of a hydrogen-doped pipeline model with corrosion defects based on the maximum permissible pressure and the Mises stress.

[0026] In some embodiments, the determining unit is further configured to determine the location of the corrosion defect on the hydrogen-doped pipeline based on the size information of the corrosion defect and the clock angle.

[0027] In some embodiments, the determining unit is further configured to determine the length of the hydrogen-doped pipe model containing corrosion defects based on the location of the corrosion defects on the hydrogen-doped pipe.

[0028] In some embodiments, the processing unit is further configured to model the hydrogen-doped pipeline based on mechanical property information, structural information, size information of corrosion defects, length of the hydrogen-doped pipeline model containing corrosion defects, and location of corrosion defects on the hydrogen-doped pipeline, to obtain a hydrogen-doped pipeline model containing corrosion defects.

[0029] In some embodiments, the processing unit is further configured to model the hydrogen-doped pipe based on mechanical property information, structural information, size information of corrosion defects, length of the hydrogen-doped pipe model containing corrosion defects, and position of corrosion defects on the hydrogen-doped pipe, to obtain a planar model of the hydrogen-doped pipe containing corrosion defects.

[0030] In some embodiments, the processing unit is further configured to convert the planar model of the hydrogen-doped pipeline with corrosion defects into a straight pipe model of the hydrogen-doped pipeline with corrosion defects.

[0031] In some embodiments, the processing unit is further configured to convert the straight pipe model of the hydrogen-doped pipeline with corrosion defects into the bent pipe model of the hydrogen-doped pipeline with corrosion defects.

[0032] In some embodiments, the determining unit is further configured to determine a length scaling factor based on the pipe radius, the pipe bending radius, and the clock angle, wherein the length scaling factor is used to determine the length of the corrosion defect model.

[0033] In some embodiments, the determining unit is further configured to determine the length of the corrosion defect model based on the length scaling factor and the length of the corrosion defect.

[0034] Thirdly, this application provides a failure pressure determination apparatus, which includes a processor and a communication interface. The communication interface is coupled to the processor, which is used to run computer programs or instructions to implement the failure pressure determination method as described in any one of the first aspects and any possible implementations of the first aspect.

[0035] Fourthly, this application provides a computer-readable storage medium storing instructions that, when executed on a terminal, cause the terminal to perform the failure pressure determination method as described in any one of the first aspects and any possible implementations of the first aspect.

[0036] Fifthly, this application provides a computer program product comprising computer instructions that, when executed on a computer, cause the computer to perform the failure pressure determination method as described in any one of the first aspects and any possible implementations of the first aspect.

[0037] It is understood that the beneficial effects that can be achieved by the second to fifth aspects provided above can be referred to the beneficial effects in any possible design of the failure pressure determination method as described in any one of the first aspects and any possible implementation of the first aspect, which will not be repeated here. Attached Figure Description

[0038] To more clearly illustrate the technical solutions of the embodiments of this application, the drawings used in the description of the embodiments 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.

[0039] Figure 1 An architecture diagram of a failure pressure determination system provided in this application embodiment;

[0040] Figure 2 A flowchart illustrating a method for determining failure pressure provided in this application embodiment. Figure 1 ;

[0041] Figure 3 A flowchart illustrating a method for determining failure pressure provided in this application embodiment. Figure 2 ;

[0042] Figure 4 A schematic diagram of corrosion defects in a hydrogen-doped pipeline provided as an embodiment of this application;

[0043] Figure 5 A flowchart illustrating a method for determining failure pressure provided in this application embodiment. Figure 3 ;

[0044] Figure 6 A flowchart illustrating a method for determining failure pressure provided in this application embodiment. Figure 4 ;

[0045] Figure 7 A schematic diagram of a wall thickness transition zone provided in an embodiment of this application;

[0046] Figure 8 A schematic diagram illustrating the process of generating a thick transition zone along the sidewall provided in this application embodiment;

[0047] Figure 9 A schematic diagram illustrating the process of generating a corner wall thickness transition zone is provided in an embodiment of this application.

[0048] Figure 10 A schematic diagram illustrating the process of generating a hydrogen-doped pipe bend model with corrosion defects, provided for an embodiment of this application;

[0049] Figure 11 This is a schematic diagram of a failure pressure determination device provided in an embodiment of this application;

[0050] Figure 12 This is a schematic diagram of another failure pressure determination device provided in an embodiment of this application. Detailed Implementation

[0051] The following description, in conjunction with the accompanying drawings, details a method, apparatus, and storage medium for determining failure pressure provided in the embodiments of this application.

[0052] In this article, the term "and / or" is merely a description of the relationship between related objects, indicating that there can be three relationships. For example, A and / or B can represent three situations: A exists alone, A and B exist simultaneously, and B exists alone.

[0053] The terms "first" and "second," etc., used in the specification and drawings of this application are used to distinguish different objects or to distinguish different treatments of the same object, rather than to describe a specific order of objects.

[0054] Furthermore, the terms "comprising" and "having," and any variations thereof, used in the description of this application are intended to cover non-exclusive inclusion. For example, a process, method, system, product, or apparatus that includes a series of steps or units is not limited to the steps or units listed, but may optionally include other steps or units not listed, or may optionally include other steps or units inherent to such process, method, product, or apparatus.

[0055] It should be noted that in the embodiments of this application, the words "exemplary" or "for example" are used to indicate examples, illustrations, or explanations. Any embodiment or design scheme described as "exemplary" or "for example" in the embodiments of this application should not be construed as being more preferred or advantageous than other embodiments or design schemes. Specifically, the use of the words "exemplary" or "for example" is intended to present the relevant concepts in a specific manner.

[0056] In the description of this application, it should be noted that, unless otherwise expressly specified and limited, the terms "installation," "connection," "linking," and "communication" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection. They can refer to a direct connection or an indirect connection through an intermediate medium, or a connection within two components. Those skilled in the art can understand the specific meaning of the above terms in this application according to the specific circumstances.

[0057] In the field of oil and gas pipeline safety maintenance, the failure pressure assessment of pipelines with corrosion defects is a crucial indicator for ensuring safe pipeline operation. As key infrastructure for long-distance transportation of oil and natural gas, the safety of oil and gas pipelines is essential for the stable operation of the entire energy supply chain. Therefore, accurately calculating the failure pressure of pipelines with corrosion defects is of great significance for ensuring the safe and stable operation of oil and gas pipelines.

[0058] With the transformation of the global energy structure and the advancement of the "dual carbon" goal, hydrogen energy is being managed in a coordinated manner alongside traditional energy sources such as oil, coal, and natural gas. This marks a new stage in the diversification of the energy structure. It is projected that by 2030, a long-distance hydrogen pipeline network exceeding 3,000 kilometers will be established, posing unprecedented challenges to the safe and efficient transportation of hydrogen energy. Currently, in the actual operation of hydrogen pipelines, some pipelines are using natural gas blending with hydrogen to mitigate the hydrogen embrittlement effect, thereby ensuring the long-term safe operation of hydrogen-blended natural gas pipelines. However, in addition to hydrogen embrittlement, the complex environmental conditions faced by buried pipelines make corrosion another crucial factor that cannot be ignored. Corrosion not only affects the structural integrity of the pipeline but may also exacerbate hydrogen-induced material degradation, thus threatening the overall safety performance of the pipeline.

[0059] In current engineering practice, failure pressure assessments for pipelines with corrosion defects largely rely on empirical formulas. While this method is convenient, it often leads to overly conservative assessment results, resulting in unnecessary pipeline excavation and a waste of human and financial resources. Furthermore, during pipeline inspections, numerous corrosion defects are typically detected. Assessing failure pressure for only a single or a small number of corrosion defects not only fails to reflect the complex realities of engineering practice but also significantly increases costs and reduces computational efficiency.

[0060] However, methods for accurately and efficiently calculating the failure pressure of pipelines containing numerous and complexly distributed corrosion defects remain scarce. More importantly, with the steady progress towards the "dual-carbon" goal and the increasing number of hydrogen-blended pipelines, the damage faced by these pipelines will no longer stem from a single factor. The combined damage resulting from the synergistic effect of hydrogen and complex corrosion defects may further exacerbate the risks to pipeline safety. Therefore, considering both practical engineering needs and current technological advancements, accurately calculating the failure pressure of hydrogen-blended natural gas pipelines with numerous and complex corrosion defects has become an urgent technical problem to be solved.

[0061] To address the aforementioned technical problems, this application provides a method for determining failure pressure. Based on the mechanical properties, structural information, corrosion defect dimensions, and clock angle of the hydrogen-doped pipeline, it accurately models the pipeline, thus highly reproducing its true state and providing support for subsequent calculations of the failure pressure. Subsequently, based on the mechanical properties and structural information, the failure pressure of the hydrogen-doped pipeline model containing corrosion defects can be quickly calculated. This provides strong technical support for the safe maintenance of hydrogen-doped pipelines and effectively prevents failures such as pipeline rupture and leakage.

[0062] The embodiments of this application will now be described in detail with reference to the accompanying drawings.

[0063] Figure 1 This is an architecture diagram of a failure pressure determination system provided in an embodiment of this application. Figure 1 As shown, the architecture includes: a hydrogen-doped pipeline 101, a tensile testing machine 102, a terminal 103, and a server 104.

[0064] The hydrogen-blended pipeline 101 can be a pipeline system used to transport hydrogen-blended natural gas.

[0065] The tensile testing machine 102 can be connected to the hydrogen-doped pipe sample 101-1 by mechanical clamping or welding. The tensile testing machine 102 can communicate with the server 104 via wired or wireless means.

[0066] Terminal 103 may be a device that provides voice and / or data connectivity to a user, a device with wireless connectivity, or other devices connected to a wireless modem. The terminal device may be at least one of a desktop computer, laptop, wireless terminal, or laptop computer. In one embodiment, terminal 103 has communication capabilities and can access a wired or wireless network.

[0067] This application embodiment does not limit the number of terminals 103 in the failure pressure determination system, and may include a ratio of... Figure 1More terminals in China 103.

[0068] Server 104 can be a standalone physical server, a server cluster consisting of multiple physical servers, a distributed file system, or at least one of the following cloud servers providing basic cloud computing services: cloud services, cloud databases, cloud computing, cloud functions, cloud storage, network services, cloud communication, middleware services, domain name services, security services, content delivery networks, and big data or artificial intelligence platforms. This application embodiment does not limit this. Of course, server 104 can also include other functions to provide more comprehensive and diversified services.

[0069] In some embodiments, the server 104 can be used to control the tensile testing machine 102 to perform tensile tests on the hydrogen-doped pipe sample 101-1 and obtain the mechanical property information of the hydrogen-doped pipe sample 101-1, that is, the mechanical property information of the hydrogen-doped pipe 101.

[0070] Terminal device 103 can be used to receive structural information of hydrogen-doped pipeline 101, size information of corrosion defects on hydrogen-doped pipeline 101, clock angle and other information uploaded by users, and can send the received information to server 104 in response to user submission. Server 104 can receive structural information of hydrogen-doped pipeline 101, size information of corrosion defects on hydrogen-doped pipeline 101 and clock angle sent by terminal 103.

[0071] Based on the above, server 104 can be used to model the hydrogen-doped pipeline 101 based on its mechanical properties, structural information, the size information of corrosion defects on the hydrogen-doped pipeline 101, and the clock angle, to obtain a hydrogen-doped pipeline model containing corrosion defects. Then, server 104 can determine the failure pressure of the hydrogen-doped pipeline model containing corrosion defects based on the mechanical properties and structural information of the hydrogen-doped pipeline 101.

[0072] Figure 2 This is a flowchart illustrating a method for determining failure pressure provided in an embodiment of this application, as shown below. Figure 2 As shown, the method is composed of Figure 1 The server shown executes a method that includes:

[0073] S201. Obtain mechanical property information, structural information, size information of corrosion defects on the hydrogen-doped pipeline, and clock angle.

[0074] The clock angle is used to characterize the circumferential location of corrosion defects on the hydrogen-doped pipeline.

[0075] Optionally, the embodiments of this application do not limit the mechanical property information of the hydrogen-doped pipeline. For example, the mechanical property information may include the tensile strength, compressive strength, hardness, elastic modulus, Poisson's ratio, yield strength, fracture toughness, stress-strain curve, etc. of the hydrogen-doped pipeline.

[0076] Optionally, the embodiments of this application do not limit the structural information of the hydrogen-doped pipeline. For example, the structural information may include the pipeline diameter, pipeline radius, pipeline bending radius, wall thickness, etc.

[0077] Optionally, this application does not limit the size information of corrosion defects on hydrogen-doped pipelines. For example, the size information of corrosion defects may include the length, width, depth, mileage, length direction coordinates, corrosion defect number, and spacing between corrosion defects.

[0078] One possible approach to obtaining the mechanical property information of a hydrogen-doped pipeline includes: an operator injecting hydrogen into the pipeline using a preset hydrogen filling method to create a hydrogen-doped pipeline in a hydrogen-rich environment, and then installing the pipeline on a tensile testing machine. Based on this, a server can control the tensile testing machine to perform a tensile test on the hydrogen-doped pipeline using a preset tensile mode, and can acquire real-time mechanical property information of the pipeline during the elastic, plastic, and fracture failure stages of the tensile test.

[0079] Optionally, the preset tensioning mode can be determined according to actual needs. For example, the preset tensioning mode can be constant rate tensioning mode, constant load tensioning mode, constant stress tensioning mode, dynamic tensioning mode, etc.

[0080] Optionally, the preset hydrogen charging method can be determined according to actual needs. For example, the preset hydrogen charging method can be electrochemical hydrogen charging, high-pressure gas phase hydrogen charging, gas phase thermal hydrogen charging, plasma hydrogen charging, etc.

[0081] Optionally, this application does not limit the hydrogen charging time. For example, the hydrogen charging time can be 3 hours, 6 hours, 12 hours or longer.

[0082] One possible approach involves obtaining the structural information of the hydrogen-doped pipeline, the size information of corrosion defects on the pipeline, and the clock angle. Specifically, this can include: the user storing the structural information of the hydrogen-doped pipeline, the size information of corrosion defects on the pipeline, and the clock angle contained in the internal inspection report into a hydrogen-doped pipeline information table. Then, the user uploads the hydrogen-doped pipeline information table to a client installed on the terminal and triggers a submission operation. The terminal can respond to the user's submission operation by sending the hydrogen-doped pipeline information table to the server.

[0083] In this embodiment of the application, the internal inspection report is obtained by inspecting the hydrogen-doped pipeline using an internal inspection instrument (such as an internal inspection robot).

[0084] Optionally, this application does not limit the storage format of the hydrogen-doped pipeline information table. For example, the hydrogen-doped pipeline information table can be an Excel file, a CSV file, or a JSON file.

[0085] S202. Based on mechanical performance information, structural information, corrosion defect size information, and clock angle, a hydrogen-doped pipeline model is created to obtain a hydrogen-doped pipeline model containing corrosion defects.

[0086] In one possible implementation, the server is equipped with finite element analysis software. The server can input the mechanical properties, structural information, corrosion defect dimensions, and clock angle of the hydrogen-doped pipeline into the finite element analysis software, and then use the software to build a model of the hydrogen-doped pipeline containing corrosion defects.

[0087] Optionally, this application does not limit the finite element software used. For example, finite element software may include ANSYS, ADINA, ABAQUS, etc.

[0088] S203. Based on mechanical performance information and structural information, determine the failure pressure of the hydrogen-doped pipeline model containing corrosion defects.

[0089] The failure pressure is the pressure value of the hydrogen-doped pipeline under conditions of leakage, rupture, or other failures when it is subjected to internal pressure.

[0090] In one possible implementation, the mechanical property information may include the tensile strength of the hydrogen-doped pipeline, and the structural information may include the pipeline diameter and wall thickness. Based on this, the server can determine the maximum permissible pressure for safe operation of the hydrogen-doped pipeline, taking into account its tensile strength, diameter, and wall thickness. Then, the server can use the finite element method to determine the Mises stress of the hydrogen-doped pipeline model containing corrosion defects. Finally, the server can determine the failure pressure of the hydrogen-doped pipeline model containing corrosion defects based on the maximum permissible pressure and the Mises stress.

[0091] Among them, the Mises stress can be used to assess whether hydrogen-doped pipelines fail under stress.

[0092] For example, the formula for calculating the maximum permissible pressure can be referred to Formula 1 below. The formula for calculating the failure pressure can be referred to Formula 2 below.

[0093]

[0094] Where, σ u Where is the tensile strength of the hydrogen-doped pipe, D is the pipe diameter, t is the wall thickness, and P is the tensile strength of the hydrogen-doped pipe. max This is the maximum permissible pressure.

[0095]

[0096] Where, σ u The tensile strength of the hydrogen-doped pipeline is given by σ1, where σ1 is the most significant of the multiple Mises stresses less than σ. u The maximum Mises stress, σ2 is the highest Mises stress among multiple Mises stresses that is greater than σ. u The minimum stress of the millisiesselin stress, t1 is the load substep number corresponding to σ1, t2 is the load substep number corresponding to σ2, P max This is the maximum permissible pressure.

[0097] Based on the above technical solution, this application can model the hydrogen-doped pipeline using the finite element method based on its mechanical properties, structural information, corrosion defect size information, and clock angle. This results in a model of the hydrogen-doped pipeline with corrosion defects, thus highly reproducing the actual state of the pipeline and providing support for subsequent calculations of its failure pressure. Furthermore, based on the mechanical properties and structural information, combined with the finite element method, the failure pressure of the hydrogen-doped pipeline model with corrosion defects can be quickly calculated. This not only provides strong technical support for the safe maintenance of hydrogen-doped pipelines but also effectively prevents pipeline rupture, leakage, and other failure problems.

[0098] In some embodiments, such as Figure 3 As shown, the above S202 may specifically include: S301-S303.

[0099] S301. Based on the size information and clock angle of the corrosion defect, determine the location of the corrosion defect on the hydrogen-doped pipeline.

[0100] One possible way to achieve this is, such as Figure 4 As shown, the dimensional information of the corrosion defect can include its length coordinates and circumferential coordinates. The server can determine the position of the corrosion defect along the length of the hydrogen-infused pipeline based on its length coordinates, length, and width. Furthermore, the server can convert the clock angle of the corrosion defect into radians on the hydrogen-infused pipeline and determine its circumferential position on the pipeline based on these radians—that is, its position along the circumference of the pipeline. Based on this, the server can determine the final location of the corrosion defect on the hydrogen-infused pipeline based on both its circumferential and length-direction positions.

[0101] For example, the formula for calculating the curvature of corrosion defects on hydrogen-doped pipelines can be referred to Formula 3 below.

[0102]

[0103] Where rad represents the radian of the corrosion defect on the hydrogen-doped pipe, and θ z Let θ be the total angle of corrosion defects on the hydrogen-doped pipeline. z The calculation formula can be found in formulas 4-6.

[0104]

[0105] θ z =θ h +θ m (Formula 6)

[0106] Where h is the hour of the clock, θ h θ is the angle corresponding to hour h, m is the minute of the clock, and θ m This refers to the angle corresponding to minutes. For example... Figure 4 As shown, the left cross-section of the hydrogen-doped pipe is considered as the surface of a clock, and the circumferential position is represented by the hour scale of a clock. For example, the 12 o'clock position represents 0° or 360°, the 3 o'clock position represents 90°, the 6 o'clock position represents 180°, and the 9 o'clock position represents 270°.

[0107] S302. Based on the location of corrosion defects on the hydrogen-doped pipeline, determine the length of the hydrogen-doped pipeline model containing corrosion defects.

[0108] In one possible implementation, the server can determine the center point of the corrosion defect based on its location on the hydrogen-doped pipe, and then determine a length threshold along both sides of the center point. The length of the hydrogen-doped pipe model containing the corrosion defect is twice the length threshold. For example, if the length threshold is N, the length of the hydrogen-doped pipe model containing the corrosion defect is 2N.

[0109] In the embodiments of this application, such as Figure 4 As shown, if a hydrogen-doped pipeline contains one corrosion defect A, then the center point is the center point of corrosion defect A. If a hydrogen-doped pipeline contains multiple corrosion defects, i.e., a corrosion defect cluster B, then the center point is the center point of corrosion defect cluster B.

[0110] Optionally, this application does not limit the length threshold. For example, the length threshold can be 3 times the diameter of the hydrogen-doped pipe or 4 times the diameter of the hydrogen-doped pipe.

[0111] S303. Based on mechanical property information, structural information, size information of corrosion defects, length of the hydrogen-doped pipe model containing corrosion defects, and location of corrosion defects on the hydrogen-doped pipe, a model of the hydrogen-doped pipe containing corrosion defects is obtained.

[0112] In one possible implementation, the server can refer to the method in S202 above to input the mechanical performance information, structural information, size information of corrosion defects, length of the hydrogen-doped pipe model containing corrosion defects, and location of corrosion defects on the hydrogen-doped pipe into the finite element analysis software, and use the finite element analysis software to establish the hydrogen-doped pipe model containing corrosion defects.

[0113] Based on the above technical solution, this application can determine the center point of the corrosion defect based on its location on the hydrogen-doped pipeline, and determine the length of the hydrogen-doped pipeline model containing the corrosion defect based on the center point of the corrosion defect and the diameter of the hydrogen-doped pipeline. This can avoid the Saint-Venant effect caused by excessively short pipeline distance. Furthermore, based on the acquired information about the hydrogen-doped pipeline and the corrosion defect, a model of the hydrogen-doped pipeline is established, which can provide technical support for calculating the failure pressure of the hydrogen-doped pipeline.

[0114] In some embodiments, the hydrogen-doped pipe can be a straight pipe or a bend, and the corrosion defect can be located at either the straight or bend of the hydrogen-doped pipe. The following description uses an example where the hydrogen-doped pipe is a bend and the corrosion defect is located at the bend to illustrate S303. Figure 5 As shown, S303 can specifically include: S501-S503.

[0115] S501. Based on mechanical performance information, structural information, size information of corrosion defects, length of the hydrogen-doped pipe model containing corrosion defects, and location of corrosion defects on the hydrogen-doped pipe, the hydrogen-doped pipe is modeled to obtain a planar model of the hydrogen-doped pipe containing corrosion defects.

[0116] One possible way to achieve this is, such as Figure 6 As shown, S501 may specifically include the following steps:

[0117] Step 1: Determine the length and width of the planar model of the hydrogen-doped pipeline containing corrosion defects.

[0118] Specifically, the hydrogen-doped pipeline includes straight sections and bends. The server can determine the length of the planar model of the hydrogen-doped pipeline with corrosion defects and the length of the bend sections based on the pipeline radius and bend angle. The server can also determine the width of the planar model of the hydrogen-doped pipeline with corrosion defects based on the pipeline diameter.

[0119] For example, the formula for calculating the width of a planar model of a hydrogen-doped pipeline with corrosion defects can be referred to Formula 7 below.

[0120] W p =πD(Formula 7)

[0121] Where D is the diameter of the hydrogen-doped pipe, Wp This represents the width of the planar model of the hydrogen-doped pipeline with corrosion defects, which is the circumferential arch length of the hydrogen-doped pipeline model with corrosion defects.

[0122] For example, the formula for calculating the length of the curved section of a hydrogen-doped pipe with corrosion defects in a planar model can be referred to Formula 8 below, and the formula for calculating the length of the straight pipes at both ends can be referred to Formula 9 below.

[0123]

[0124] Among them, a b R is the bending angle of the pipe, R is the bending radius of the hydrogen-doped pipe, and L is the bending angle of the pipe. b The length of the curved section of the hydrogen-doped pipeline in the planar model containing corrosion defects.

[0125] L p =2L S +L b (Formula 9)

[0126] Among them, L S L is the length of the straight pipes at both ends. p The length of the planar model of the hydrogen-doped pipeline containing corrosion defects.

[0127] Step 2: Determine the dimensional information of the corrosion defect model in the planar model of the hydrogen-doped pipeline containing corrosion defects.

[0128] Specifically, determining the length of the corrosion defect model can include: the server determining a length scaling factor based on the pipe radius, pipe bend radius, and clock angle. Then, the server can determine the length of the corrosion defect model based on the length scaling factor and the length of the corrosion defect.

[0129] The length scaling factor is used to determine the length of the corrosion defect model. The corrosion defect model is derived from modeling corrosion defects on hydrogen-doped pipelines.

[0130] For example, the formula for calculating the length of the corrosion defect model can be referred to Formula 10 below.

[0131] L s =L×s f (Formula 10)

[0132] Among them, L s s represents the length of the corrosion defect model, L represents the length of the corrosion defect on the hydrogen-doped pipeline, and s represents the length of the corrosion defect model. f This is the length scaling factor. For specific calculation formulas, please refer to Formulas 11-13 below.

[0133]

[0134] R0=Rr×cosθc (Formula 12)

[0135] θ c =h×30+m×0.5 (Formula 13)

[0136] Where R is the bending radius of the hydrogen-doped pipe, r is the pipe radius of the hydrogen-doped pipe, R0 is the horizontal distance from the center of the corrosion defect to the center of curvature, h is the hour, m is the minute, and θ c From the perspective of corrosion defects.

[0137] Specifically, the server can determine the depth of the corrosion defect model based on the wall thickness of the hydrogen-doped pipe and the depth of corrosion defects on the hydrogen-doped pipe.

[0138] For example, the depth d of the corrosion defect model c The calculation formula can be found in Formula 14 below.

[0139]

[0140] Where, d f t represents the depth of corrosion defects on the hydrogen-doped pipeline, and t represents the wall thickness of the hydrogen-doped pipeline.

[0141] Step 3: Based on the determined length, width, and size information of the corrosion defect model in the planar model of the hydrogen-doped pipeline containing corrosion defects, generate a planar model of the hydrogen-doped pipeline containing corrosion defects.

[0142] Specifically, the planar model of a hydrogen-doped pipeline with corrosion defects can include corroded regions, non-corroded regions, and wall thickness transition zones (edge ​​wall thickness transition zones and corner wall thickness transition zones). The methods for generating the corroded and non-corroded regions can refer to the methods in S202 above, and will not be repeated here. The following description uses the methods for generating the edge and corner wall thickness transition zones as examples.

[0143] like Figure 7 As shown in the embodiment of this application, the wall thickness transition zone is divided into five parts according to the orientation: "east, west, south, north, and corner". These are the east wall thickness transition zone, west wall thickness transition zone, south wall thickness transition zone, north wall thickness transition zone, and corner wall thickness transition zone. The corner wall thickness transition zone may include the northeast corner wall thickness transition zone, southeast corner wall thickness transition zone, northwest corner wall thickness transition zone, and southwest corner wall thickness transition zone.

[0144] In one example, taking the thick transition zone of the north wall as an example, such as Figure 8As shown, the server can pre-define a base element with a wall thickness transition of 1 unit length. Then, based on the lengths of the corroded and non-corroded elements adjacent to the north wall thickness transition zone, the coordinates of all nodes in the base element are scaled. Finally, the scaled base element can be copied to obtain a complete set of north wall thickness transition zones (also called north side wall thickness transition zones). The generation process of the side wall thickness transition zones in the east, west, and south directions can refer to the generation method of the north wall thickness transition zone, and will not be elaborated here.

[0145] In one example, the northeast corner wall thickness transition zone, such as Figure 9 As shown, the server can preset a corner base element with a wall thickness transition of 1 for each element. Then, based on the lengths of the corroded area elements and the non-corroded area elements adjacent to the northeast corner wall thickness transition zone, the coordinates of all nodes of the corner base element are scaled to obtain the northeast corner wall thickness transition zone. The generation process of the corner wall thickness transition zones in the southeast, northwest, and southwest directions can refer to the generation method of the northeast corner wall thickness transition zone, and will not be elaborated here.

[0146] S502. Convert the planar model of the hydrogen-doped pipeline with corrosion defects into a straight pipe model of the hydrogen-doped pipeline with corrosion defects.

[0147] Specifically, the planar model of the hydrogen-doped pipeline with corrosion defects contains multiple elements, and each element contains multiple nodes. The server can extract all nodes and the coordinates of each node from the planar model of the hydrogen-doped pipeline with corrosion defects, and store the node number and its corresponding coordinates in a node matrix. Simultaneously, the server can also extract all elements from the planar model of the hydrogen-doped pipeline with corrosion defects and store each element in an element matrix.

[0148] For example, the expression for the node matrix can be found in Formula 15 below, and the expression for the cell matrix can be found in Formula 13 above.

[0149]

[0150] Wherein, the node matrix N shell The first column represents the node number, and the second to fourth columns represent the x, y, and z coordinates of the node, respectively.

[0151]

[0152] Wherein, the identity matrix E shell Each row represents the nodes contained in each cell.

[0153] Based on the above, the server can use cylindrical coordinate transformation based on the node matrix and element matrix to convert the coordinates of the nodes in the plane model of the hydrogen-doped pipeline with corrosion defects into the corresponding straight pipe coordinates, thus obtaining the straight pipe model of the hydrogen-doped pipeline with corrosion defects.

[0154] For example, the calculation formula for the coordinates of each node in the straight pipe model of a hydrogen-doped pipeline with corrosion defects can be referred to Formulas 17-19 below.

[0155]

[0156] z s =y0(Formula 19)

[0157] Among them, (x s ,y s ,z s (z0, y0) represents the coordinates of a node in the straight pipe model of the hydrogen-doped pipeline with corrosion defects, and (z0, y0) represents the coordinates of a node in the planar model of the hydrogen-doped pipeline with corrosion defects.

[0158] S503. Convert the straight pipe model of the hydrogen-doped pipeline with corrosion defects into the bent pipe model of the hydrogen-doped pipeline with corrosion defects.

[0159] Specifically, the server can use coordinate transformation to convert the coordinates of each node in the straight pipe model of the hydrogen-doped pipeline with corrosion defects into the coordinates of each node in the corresponding bend model of the hydrogen-doped pipeline with corrosion defects. Then, all nodes and their coordinates in the bend model are stored in a node matrix, and all elements are stored in an element matrix. Next, the server can store the node and element matrix data in a text file and process all node and element information using batch processing commands. Finally, based on the processed node and element information, the bend model of the hydrogen-doped pipeline with corrosion defects is generated. The expressions for the node and element matrices of the bend model can be found in Equations 15 and 16 above, and will not be elaborated upon here.

[0160] For example, the calculation formula for the node coordinates of the bending section in the model of a hydrogen-doped pipe with corrosion defects can be referred to Formulas 20-23 below.

[0161] a b =z s / r(Formula 20)

[0162] x b =Rx s cos(a b )(Formula 21)

[0163] y b =y s (Formula 22)

[0164] z b =Rx b sin(a b )(Formula 23)

[0165] Among them, (x b ,y b ,z b ) represents the coordinates of a node in a hydrogen-doped pipe bend model containing corrosion defects, and a b This is the bending angle vector of a hydrogen-doped pipe bend model containing corrosion defects.

[0166] For example, Figure 10 A schematic diagram illustrating the process of generating a hydrogen-doped pipe bend model with corrosion defects is shown. Figure 10 As shown, the server can convert a planar model of a hydrogen-doped pipeline containing elliptical corrosion defects into a straight pipe model of the same defects. Then, the server can further convert this straight pipe model into a bend model of the same defects.

[0167] Based on the above technical solution, a model of a hydrogen-doped pipeline bend containing corrosion defects can be quickly generated. This model can accurately reproduce the mechanical properties, structural information, and corrosion defect information of the hydrogen-doped pipeline, and also provide technical support for subsequent calculation of the failure pressure of the hydrogen-doped pipeline.

[0168] Figure 11 This application provides a schematic diagram of the structure of a failure pressure determination device, as shown in the embodiments below. Figure 11 As shown, the device includes:

[0169] The acquisition unit 1101 is used to acquire mechanical property information, structural information, size information of corrosion defects on the hydrogen-doped pipeline, and clock angle. The clock angle is used to characterize the circumferential position of corrosion defects on the hydrogen-doped pipeline.

[0170] The processing unit 1102 is used to model the hydrogen-doped pipeline based on mechanical property information, structural information, corrosion defect size information and clock angle, to obtain a hydrogen-doped pipeline model with corrosion defects.

[0171] Unit 1103 is used to determine the failure pressure of a hydrogen-doped pipeline model containing corrosion defects based on mechanical property information and structural information. The failure pressure is the pressure value of the hydrogen-doped pipeline under conditions of leakage, rupture, or other failures when subjected to internal pressure.

[0172] In some embodiments, the determining unit 1103 is further configured to determine the maximum permissible pressure for safe operation of the hydrogen-doped pipeline based on the tensile strength, diameter, and wall thickness of the hydrogen-doped pipeline.

[0173] In some embodiments, the determining unit 1103 is further configured to determine the Mises stress of a hydrogen-doped pipe model containing corrosion defects using the finite element method.

[0174] In some embodiments, the determining unit 1103 is further configured to determine the failure pressure of the hydrogen-doped pipeline model containing corrosion defects based on the maximum permissible pressure and the Mises stress.

[0175] In some embodiments, the determining unit 1103 is further configured to determine the location of the corrosion defect on the hydrogen-doped pipeline based on the size information of the corrosion defect and the clock angle.

[0176] In some embodiments, the determining unit 1103 is further configured to determine the length of the hydrogen-doped pipeline model containing corrosion defects based on the location of the corrosion defects on the hydrogen-doped pipeline.

[0177] In some embodiments, the processing unit 1102 is further configured to model the hydrogen-doped pipe based on mechanical property information, structural information, size information of corrosion defects, length of the hydrogen-doped pipe model containing corrosion defects, and position of corrosion defects on the hydrogen-doped pipe, to obtain a hydrogen-doped pipe model containing corrosion defects.

[0178] In some embodiments, the processing unit 1102 is further configured to model the hydrogen-doped pipe based on mechanical property information, structural information, size information of corrosion defects, length of the hydrogen-doped pipe model containing corrosion defects, and position of corrosion defects on the hydrogen-doped pipe, to obtain a planar model of the hydrogen-doped pipe containing corrosion defects.

[0179] In some embodiments, the processing unit 1102 is further configured to convert the planar model of the hydrogen-doped pipeline with corrosion defects into a straight pipe model of the hydrogen-doped pipeline with corrosion defects.

[0180] In some embodiments, the processing unit 1102 is further configured to convert the straight pipe model of the hydrogen-doped pipeline with corrosion defects into the bent pipe model of the hydrogen-doped pipeline with corrosion defects.

[0181] In some embodiments, the determining unit 1103 is further configured to determine a length scaling factor based on the pipe radius, the pipe bending radius, and the clock angle, wherein the length scaling factor is used to determine the length of the corrosion defect model.

[0182] In some embodiments, the determining unit 1103 is further configured to determine the length of the corrosion defect model based on the length scaling factor and the length of the corrosion defect.

[0183] Figure 12A schematic diagram of another possible structure of the failure pressure determination device involved in the above embodiments is shown. The failure pressure determination device includes a processor 1201 and a communication interface 1202. The processor 1201 is used to control and manage the operation of the failure pressure determination device, and the communication interface 1202 is used to support communication between the failure pressure determination device and other network entities. The failure pressure determination device may also include a memory 1203 and a bus 1204. The memory 1203 is used to store the program code and data of the failure pressure determination device.

[0184] The memory 1203 may be a memory in a failure pressure determination device, and the memory may include volatile memory, such as random access memory; the memory may also include non-volatile memory, such as read-only memory, flash memory, hard disk or solid-state drive; the memory may also include a combination of the above types of memory.

[0185] The processor 1201 described above can implement or execute various exemplary logic blocks, modules, and circuits described in conjunction with the disclosure of this application. The processor can be a central processing unit, a general-purpose processor, a digital signal processor, an application-specific integrated circuit (ASIC), a field-programmable gate array (FPGA), or other programmable logic devices, transistor logic devices, hardware components, or any combination thereof. It can implement or execute various exemplary logic blocks, modules, and circuits described in conjunction with the disclosure of this application. The processor can also be a combination that implements computational functions, such as including one or more microprocessor combinations, a combination of a DSP and a microprocessor, etc.

[0186] Bus 1204 can be an extended industry standard architecture (EISA) bus, etc. Bus 1204 can be divided into address bus, data bus, control bus, etc. For ease of representation, Figure 12 The bus is represented by a single thick line, but this does not mean that there is only one bus or one type of bus.

[0187] Through the above description of the embodiments, those skilled in the art will clearly understand that, for the sake of convenience and brevity, only the division of the above functional modules is used as an example. In practical applications, the above functions can be assigned to different functional modules as needed, that is, the internal structure of the device can be divided into different functional modules to complete all or part of the functions described above. The specific working process of the system, device, and unit described above can be referred to the corresponding process in the foregoing method embodiments, and will not be repeated here.

[0188] This application provides a computer program product containing instructions that, when run on a computer, cause the computer to execute the failure pressure determination method in the above method embodiments.

[0189] This application also provides a computer-readable storage medium storing instructions that, when executed on a computer, cause the computer to perform the failure pressure determination method in the method flow shown in the above method embodiments.

[0190] The computer-readable storage medium may be, for example, but not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination thereof. More specific examples (a non-exhaustive list) of computer-readable storage media include: electrical connections having one or more wires; portable computer disks; hard disks; random access memory (RAM); read-only memory (ROM); erasable programmable read-only memory (EPROM); registers; hard disks; optical fibers; compact disc read-only memory (CD-ROM); optical storage devices; magnetic storage devices; or any suitable combination thereof; or any other form of computer-readable storage medium known in the art. An exemplary storage medium is coupled to a processor, enabling the processor to read information from and write information to the storage medium. Of course, the storage medium may also be a component of the processor. The processor and the storage medium may reside in an application-specific integrated circuit (ASIC). In the embodiments of this application, the computer-readable storage medium can be any tangible medium that contains or stores a program that can be used by or in conjunction with an instruction execution system, apparatus, or device.

[0191] Embodiments of the present invention provide a computer program product containing instructions that, when executed on a computer, cause the computer to perform the failure pressure determination method described in the embodiments of this application.

[0192] Since the failure pressure determination device, computer-readable storage medium, and computer program product in the embodiments of the present invention can be applied to the above method, the technical effects obtained can also be referred to the above method embodiments. The embodiments of the present invention will not be repeated here.

[0193] In the several embodiments provided in this application, it should be understood that the disclosed systems, devices, and methods can be implemented in other ways. For example, the device embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the mutual coupling or direct coupling or communication connection shown or discussed may be through some interfaces; the indirect coupling or communication connection between devices or units may be electrical, mechanical, or other forms.

[0194] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0195] In addition, the functional units in the various embodiments of this application can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit.

[0196] The above are merely specific embodiments of this application, but the scope of protection of this application is not limited thereto. Any variations or substitutions within the technical scope disclosed in this application should be included within the scope of protection of this application. Therefore, the scope of protection of this application should be determined by the scope of the claims.

Claims

1. A method for determining failure pressure, characterized in that, The method includes: The mechanical properties, structural information, size information of corrosion defects on the hydrogen-doped pipeline, and clock angle are obtained; the clock angle is used to characterize the circumferential position of the corrosion defects on the hydrogen-doped pipeline. Based on the mechanical performance information, the structural information, the size information of the corrosion defects, and the clock angle, the hydrogen-doped pipeline is modeled to obtain a hydrogen-doped pipeline model containing corrosion defects. Based on the mechanical property information and the structural information, the failure pressure of the hydrogen-doped pipeline model with corrosion defects is determined; the failure pressure is the pressure value of the hydrogen-doped pipeline under conditions of leakage, rupture or other failure when subjected to internal pressure.

2. The method according to claim 1, characterized in that, The mechanical property information includes the tensile strength of the hydrogen-doped pipe, and the structural information includes the pipe diameter and wall thickness of the hydrogen-doped pipe; The determination of the failure pressure of the hydrogen-doped pipeline model with corrosion defects based on the mechanical property information and the structural information includes: Based on the tensile strength, pipe diameter, and wall thickness of the hydrogen-infused pipeline, the maximum permissible pressure for safe operation of the hydrogen-infused pipeline is determined. The finite element method was used to determine the Mises stress of the hydrogen-doped pipeline model containing corrosion defects; the Mises stress was used to assess whether the hydrogen-doped pipeline would fail under stress. Based on the maximum permissible pressure and the Mises stress, the failure pressure of the hydrogen-doped pipeline model with corrosion defects is determined.

3. The method according to claim 2, characterized in that, The number of Mises stresses is multiple; The failure pressure satisfies the following formula: Where, σ u σ1 is the tensile strength of the hydrogen-doped pipeline, where σ1 is the smallest Mises stress less than σ1. u The maximum Mises stress, σ2, is the highest Mises stress among the plurality of Mises stresses that is greater than σ. u The minimum stress of the millisiesselin stress, t1 is the load substep number corresponding to σ1, t2 is the load substep number corresponding to σ2, P max This refers to the maximum permissible pressure.

4. The method according to claim 3, characterized in that, The maximum permissible pressure satisfies the following formula: Where, σ u Let P be the tensile strength of the hydrogen-doped pipe, D be the pipe diameter, t be the wall thickness, and P be the tensile strength of the hydrogen-doped pipe. max This refers to the maximum permissible pressure.

5. The method according to claim 1, characterized in that, The hydrogen-doped pipeline is modeled based on the mechanical property information, the structural information, the size information of the corrosion defects, and the clock angle to obtain a hydrogen-doped pipeline model containing corrosion defects, including: Based on the size information and clock angle of the corrosion defect, the location of the corrosion defect on the hydrogen-doped pipeline is determined; Based on the location of the corrosion defects on the hydrogen-doped pipeline, the length of the hydrogen-doped pipeline model containing the corrosion defects is determined; Based on the mechanical property information, the structural information, the size information of the corrosion defects, the length of the hydrogen-doped pipe model containing the corrosion defects, and the position of the corrosion defects on the hydrogen-doped pipe, the hydrogen-doped pipe is modeled to obtain the hydrogen-doped pipe model containing the corrosion defects.

6. The method according to claim 5, characterized in that, The hydrogen-doped pipe is a bend, and the corrosion defect is located at the bend of the hydrogen-doped pipe. The process of modeling the hydrogen-doped pipeline based on the mechanical property information, the structural information, the size information of the corrosion defects, the length of the hydrogen-doped pipeline model containing the corrosion defects, and the position of the corrosion defects on the hydrogen-doped pipeline, to obtain the hydrogen-doped pipeline model containing the corrosion defects, includes: Based on the mechanical property information, the structural information, the size information of the corrosion defects, the length of the hydrogen-doped pipe model containing corrosion defects, and the position of the corrosion defects on the hydrogen-doped pipe, the hydrogen-doped pipe is modeled to obtain a planar model of the hydrogen-doped pipe containing corrosion defects. The planar model of the hydrogen-doped pipeline with corrosion defects is converted into a straight pipe model of the hydrogen-doped pipeline with corrosion defects. The straight pipe model of the hydrogen-doped pipeline with corrosion defects is converted into a bent pipe model of the hydrogen-doped pipeline with corrosion defects.

7. The method according to claim 6, characterized in that, The structural information includes the pipe radius and pipe bending radius of the hydrogen-doped pipe, and the size information of the corrosion defect includes the length of the corrosion defect on the hydrogen-doped pipe; The length of the corrosion defect model in the planar model of the hydrogen-doped pipeline containing corrosion defects is determined in the following way: The length scaling factor is determined based on the pipe radius, the pipe bending radius, and the clock angle; The length scaling factor is used to determine the length of the corrosion defect model; The length of the corrosion defect model is determined based on the length scaling factor and the length of the corrosion defect; the corrosion defect model is obtained by modeling the corrosion defects on the hydrogen-doped pipeline.

8. A failure pressure determination device, characterized in that, The device includes: The acquisition unit acquires the mechanical properties, structural information, size information of corrosion defects on the hydrogen-doped pipeline, and clock angle; the clock angle is used to characterize the circumferential position of the corrosion defects on the hydrogen-doped pipeline. The processing unit models the hydrogen-doped pipeline based on the mechanical performance information, the structural information, the size information of the corrosion defects, and the clock angle, to obtain a hydrogen-doped pipeline model containing corrosion defects. The determining unit determines the failure pressure of the hydrogen-doped pipeline model containing corrosion defects based on the mechanical property information and the structural information; the failure pressure is the pressure value of the hydrogen-doped pipeline under leakage, rupture or other failure conditions when subjected to internal pressure.

9. A failure pressure determination device, characterized in that, include: A processor and a communication interface; the communication interface is coupled to the processor, the processor being used to run computer programs or instructions to implement the failure pressure determination method as described in any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores instructions that, when executed by a computer, perform the failure pressure determination method as described in any one of claims 1-7.

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