Method and system for predicting corrosion life of a nuclear power plant cold insulation pipeline, storage medium and equipment

Abstract

This invention discloses a method, system, storage medium, and equipment for predicting the corrosion life of insulated pipelines in nuclear power plants. The method includes the following steps: Step S10: Obtain the coating failure time of the target pipeline; Step S20: Obtain the pipeline failure time of the target pipeline; Step S30: Obtain the cumulative corrosion exposure time data of the target pipeline, and calculate the remaining service life of the target pipeline by combining the coating failure time and the pipeline failure time. This method can predict the remaining service life of pipelines in advance, effectively solving the pain point of existing technologies that can only detect after the fact and cannot make advance assessments. It can achieve advance control of corrosion of insulated pipelines, eliminating the need for frequent large-scale removal of the insulation layer for offline inspection, significantly reducing the workload of on-site operation and maintenance, and avoiding structural damage and accelerated corrosion caused by repeated disassembly and reassembly of the insulation layer, effectively improving the operational safety and reliability of the nuclear power plant's chilled water system.

Description

Technical Field

[0001] This invention relates to the field of corrosion life prediction technology for cold-insulated pipelines in nuclear power plants, and particularly to a method, system, storage medium, and equipment for predicting the corrosion life of cold-insulated pipelines in nuclear power plants. Background Technology

[0002] The chilled water system of a nuclear power plant is a key auxiliary system inside and outside the controlled area, providing a stable cold source for various equipment. The structural integrity of its insulation pipelines directly determines the operational reliability of the chilled water system, and thus affects the safe and stable operation of the nuclear power plant.

[0003] The temperature of the medium transported in the cold-insulated pipeline is typically around 7°C, far lower than the ambient temperature in the plant (usually around 25°C), resulting in a significant temperature difference between the pipeline's outer wall and the ambient air. To prevent heat input and condensation of water vapor in the air, centrifugal glass wool is wrapped around the outer wall of the pipeline for insulation, blocking heat exchange between the pipeline wall and the environment and inhibiting condensation. However, existing insulation structures have inherent defects such as discontinuous insulation wrapping and inadequate end sealing at irregular locations like pipeline ends and valve interfaces. This fails to completely prevent humid air from contacting the cold pipeline wall, causing condensation to continue to form at the pipeline ends and seep deeper into the pipeline, gradually wetting the insulation. The wetting insulation layer keeps the pipeline's outer wall in a high-humidity environment for extended periods. Under prolonged immersion, the anti-corrosion coating on the pipeline wall gradually fails, leading to corrosion of the pipeline substrate. As the corrosion depth increases, the pipeline wall thickness continues to decrease, eventually causing pipeline perforation and media leakage, severely impacting the reliability of the system.

[0004] Currently, corrosion control of cold-insulated pipelines can only be carried out through visual inspection and other means. During the inspection process, a large area of ​​pipeline insulation needs to be removed, which not only brings a huge amount of on-site work, but the frequent disassembly and reassembly of the insulation layer will also damage its structural integrity and weaken the insulation and cold-insulating effect, which will further aggravate the corrosion process of the pipeline. Summary of the Invention

[0005] The technical problem to be solved by the present invention is to provide a method, system, storage medium and equipment for predicting the corrosion life of cold insulation pipes in nuclear power plants.

[0006] The technical solution adopted by this invention to solve its technical problem is: to provide a method for predicting the corrosion life of cold-insulated pipes in nuclear power plants, comprising the following steps: Step S10: Obtain the coating failure time of the target pipeline; Step S20: Obtain the pipe failure time of the target pipe; Step S30: Obtain the cumulative corrosion exposure time data of the target pipeline, and calculate the remaining service life of the target pipeline by combining the coating failure time and the pipeline failure time.

[0007] Further, step S10 includes: Step S11: Obtain basic input parameters, including coating intrinsic performance parameters, pipeline operating condition parameters, insulation material parameters, and environmental parameters; the coating intrinsic performance parameters include coating intrinsic design life t0, cold wall effect proportionality constant k1, wetting expansion effect proportionality constant k2, and coating saturated water absorption rate ω. sat Coating swelling coefficient β, water diffusion coefficient D in the coating, and dry film thickness d of the coating. c The pipeline operating parameters include the ambient-pipe wall temperature difference ΔT; the insulation material parameters include the thermal conductivity λ of the insulation layer in a dry state. dry The thermal conductivity λ of the insulation layer under saturated wet state of condensate water wet The environmental parameters include the relative humidity (RH) of the environment in which the pipeline is located. Step S12: Calculate the acceleration coefficient C of the cold wall effect. cold The acceleration coefficient of the cold wall effect, C cold The calculation formula is: In the formula: C cold k is the acceleration coefficient of the cold wall effect; k1 is the proportionality constant of the cold wall effect, in °C. -1 ΔT represents the ambient temperature difference between the environment and the pipe wall, in °C; λ wet / λ dry The ratio of thermal conductivity before and after the insulation layer is wetted; RH is the ambient relative humidity. Step S13: Calculate the coating swelling acceleration coefficient C swell Coating swelling acceleration coefficient C swell The calculation formula is: In the formula: C swell k1 is the coating swelling acceleration coefficient; k2 is the swelling effect proportionality constant, in seconds. 0.5 ;ω sat β is the saturated water absorption rate of the coating; D is the wetting coefficient of the coating; d is the diffusion coefficient of water in the coating, in µm² / s; c The dry film thickness of the coating is expressed in µm. Step S14: Based on the acceleration coefficient C of the cold wall effect cold With the coating swelling acceleration coefficient C swell Calculate the acceleration term of cold wall-lubrication coupling. Cold wall-lubrication expansion coupling acceleration term The calculation formula is: In the formula: For the cold wall-lubrication coupling acceleration term, C coldC is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient; Step S15: Design life based on coating intrinsic design Acceleration term coupled with cold wall-lubrication expansion Calculate the coating failure time Coating failure time The calculation formula is: In the formula: The coating failure time is expressed in years. The intrinsic design life of the coating; For the cold wall-lubrication expansion coupling acceleration term; C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient.

[0008] Further, step S20 includes: Step S21: Obtain the pipeline design corrosion allowance C; Step S22: Obtain corrosion rate data and determine the maximum local corrosion rate. ; Step S23: Based on the pipeline design corrosion allowance C and the maximum local corrosion rate Calculate the pipeline failure time of the target pipeline. The failure time of the target pipeline The calculation formula is: In the formula: The pipeline failure time is expressed in years. The corrosion allowance for pipeline design is expressed in mm. This represents the maximum local corrosion rate.

[0009] Furthermore, in step S30, the remaining service life of the target pipeline is... The calculation formula is: In the formula: The remaining service life of the target pipeline, in years; The coating failure time is expressed in years. t represents the pipeline failure time in years; t represents the cumulative corrosion exposure time of the target pipeline in years.

[0010] This invention also provides a corrosion life prediction system for cold-insulated pipes in nuclear power plants, comprising: The first processing module is used to obtain the coating failure time of the target pipeline; The second processing module is used for the pipeline failure time of the target pipeline; The third processing module is used to acquire the cumulative corrosion exposure time data of the target pipeline, and calculate the remaining service life of the target pipeline by combining the coating failure time and the pipeline failure time.

[0011] Further, the first processing module includes: The first processing unit is used to acquire basic input parameters, including coating intrinsic performance parameters, pipeline operating condition parameters, insulation material parameters, and environmental parameters. The coating intrinsic performance parameters include coating intrinsic design life t0, cold wall effect proportionality constant k1, wetting expansion effect proportionality constant k2, and coating saturated water absorption rate ω. sat Coating swelling coefficient β, water diffusion coefficient D in the coating, and dry film thickness d of the coating. c The pipeline operating parameters include the ambient-pipe wall temperature difference ΔT; the insulation material parameters include the thermal conductivity λ of the insulation layer in a dry state. dry The thermal conductivity λ of the insulation layer under saturated wet state of condensate water wet The environmental parameters include the relative humidity (RH) of the environment in which the pipeline is located. The second processing unit is used to calculate the acceleration coefficient C of the cold wall effect. cold The acceleration coefficient of the cold wall effect, C cold The calculation formula is: In the formula: C cold k is the acceleration coefficient of the cold wall effect; k1 is the proportionality constant of the cold wall effect, in °C. -1 ΔT represents the ambient temperature difference between the environment and the pipe wall, in °C; λ wet / λ dry The ratio of thermal conductivity before and after the insulation layer is wetted; RH is the ambient relative humidity. The third processing unit is used to calculate the coating swelling acceleration coefficient C. swell Coating swelling acceleration coefficient C swell The calculation formula is: In the formula: C swell k1 is the coating swelling acceleration coefficient; k2 is the swelling effect proportionality constant, in seconds. 0.5 ;ω sat β is the saturated water absorption rate of the coating; D is the wetting coefficient of the coating; d is the diffusion coefficient of water in the coating, in µm² / s; c The dry film thickness of the coating is expressed in µm. The fourth processing unit is used to determine the acceleration coefficient C based on the cold wall effect. cold With the coating swelling acceleration coefficient C swellCalculate the acceleration term of cold wall-lubrication coupling. Cold wall-lubrication expansion coupling acceleration term The calculation formula is: In the formula: For the cold wall-lubrication coupling acceleration term, C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient; The fifth processing unit is used to determine the intrinsic design life of the coating. Acceleration term coupled with cold wall-lubrication expansion Calculate the coating failure time Coating failure time The calculation formula is: In the formula: The coating failure time is expressed in years. The intrinsic design life of the coating; For the cold wall-lubrication expansion coupling acceleration term; C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient.

[0012] Furthermore, the second processing module includes: The first processing subunit is used to obtain the pipeline design corrosion allowance C; The second processing subunit is used to acquire corrosion rate data and obtain the maximum local corrosion rate. ; The third processing subunit is used to determine the pipeline design corrosion allowance C and the maximum local corrosion rate. Calculate the pipeline failure time of the target pipeline. The failure time of the target pipeline The calculation formula is: In the formula: The pipeline failure time is expressed in years. The corrosion allowance for pipeline design is expressed in mm. This represents the maximum local corrosion rate.

[0013] Furthermore, the third processing module is used to determine the remaining service life of the target pipeline. The calculation formula calculates the remaining service life of the target pipeline. Among them, the remaining service life of the target pipeline The calculation formula is: In the formula: The remaining service life of the target pipeline, in years; The coating failure time is expressed in years. t represents the pipeline failure time in years; t represents the cumulative corrosion exposure time of the target pipeline in years.

[0014] The present invention also provides a storage medium storing a computer program, which, when executed, implements the steps of the method for predicting the corrosion life of nuclear power plant cold insulation pipes described above.

[0015] The present invention also provides a computer device, including a memory and a processor, wherein the memory stores a computer program that can run on the processor, and the processor executes the computer program to implement the steps of the method for predicting the corrosion life of nuclear power plant cold insulation pipes described above.

[0016] The implementation of this invention has the following beneficial effects: This method for predicting the corrosion life of cold-insulated pipelines in nuclear power plants is designed for corrosion scenarios caused by condensate wetting at the ends of cold-insulated pipelines in nuclear power plants. It constructs a quantitative calculation model for the entire process from the failure of the anti-corrosion coating to the corrosion failure of the pipeline substrate, which can realize the early prediction of the remaining service life of the pipeline and effectively solve the pain point of existing technologies that can only detect after the fact and cannot make advance assessments.

[0017] Based on the life prediction results of the corrosion life prediction method for the cold insulation pipelines in nuclear power plants, the corrosion of the cold insulation pipelines can be controlled in advance without the need for frequent large-scale removal of the insulation layer for offline inspection, which greatly reduces the workload of on-site operation and maintenance. At the same time, it avoids the structural damage and corrosion aggravation caused by repeated disassembly and reassembly of the insulation layer, effectively improving the operational safety and reliability of the chilled water system of the nuclear power plant.

[0018] The corrosion life prediction method for nuclear power plant cold-insulated pipelines can output quantitative data on the remaining life of the pipelines, providing a reliable technical basis for the formulation of maintenance plans, anti-corrosion maintenance decisions, and optimization of replacement cycles for nuclear power plant cold-insulated pipelines. Attached Figure Description

[0019] To more clearly illustrate the technical solution of the present invention, the present invention will be further described below in conjunction with the accompanying drawings and embodiments. It should be understood that the following drawings only show some embodiments of the present invention and should not be considered as a limitation of the scope. For those skilled in the art, other related drawings can be obtained from these drawings without creative effort. In the drawings: Figure 1 This is a flowchart of a method for predicting the corrosion life of cold-insulated pipes in nuclear power plants according to some embodiments of the present invention; Figure 2 This is a fitting curve diagram of the k1 calibration value in some embodiments of the present invention; Figure 3 This is a fitting curve diagram of the k2 calibration value in some embodiments of the present invention; Figure 4 This is a fitting curve of the η calibration value in some embodiments of the present invention. Detailed Implementation

[0020] To provide a clearer understanding of the technical features, objectives, and effects of this invention, specific embodiments are now described in detail with reference to the accompanying drawings. In the following description, it should be understood that the orientations or positional relationships indicated by terms such as "front," "rear," "upper," "lower," "left," "right," "longitudinal," "horizontal," "vertical," "horizontal," "top," "bottom," "inner," "outer," "head," and "tail" are based on the orientations or positional relationships shown in the accompanying drawings, and are constructed and operated in a specific orientation. They are only for the convenience of describing this technical solution and do not indicate that the device or element referred to must have a specific orientation; therefore, they should not be construed as limitations on this invention.

[0021] It should also be noted that, unless otherwise explicitly specified and limited, terms such as "installation," "connection," "linking," "fixing," and "setting" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral part; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; they can refer to the internal communication of two components or the interaction between two components. When an component is referred to as being "on" or "below" another component, the component can be located "directly" or "indirectly" on the other component, or there may be one or more intermediary components. The terms "first," "second," "third," etc., are only for the convenience of describing this technical solution and should not be construed as indicating or implying relative importance or implicitly specifying the number of indicated technical features. Therefore, features defined with "first," "second," "third," etc., may explicitly or implicitly include one or more of that feature. For those skilled in the art, the specific meaning of the above terms in this invention can be understood according to the specific circumstances.

[0022] 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 the invention. However, those skilled in the art will understand that the invention can be implemented in other embodiments without these specific details. In other instances, detailed descriptions of well-known systems, apparatuses, circuits, and methods are omitted so as not to obscure the description of the invention with unnecessary detail.

[0023] The chilled water system of a nuclear power plant is a key auxiliary system inside and outside the controlled area, providing a stable cold source for various equipment. The structural integrity of its insulation pipelines directly determines the operational reliability of the chilled water system, and thus affects the safe and stable operation of the nuclear power plant.

[0024] The temperature of the medium transported in the cold-insulated pipeline is typically around 7°C, far lower than the ambient temperature in the plant (usually around 25°C), resulting in a significant temperature difference between the pipeline's outer wall and the ambient air. To prevent heat input and condensation of water vapor in the air, centrifugal glass wool is wrapped around the outer wall of the pipeline for insulation, blocking heat exchange between the pipeline wall and the environment and inhibiting condensation. However, existing insulation structures have inherent defects such as discontinuous insulation wrapping and inadequate end sealing at irregular locations like pipeline ends and valve interfaces. This fails to completely prevent humid air from contacting the cold pipeline wall, causing condensation to continue to form at the pipeline ends and seep deeper into the pipeline, gradually wetting the insulation. The wetting insulation layer keeps the pipeline's outer wall in a high-humidity environment for extended periods. Under prolonged immersion, the anti-corrosion coating on the pipeline wall gradually fails, leading to corrosion of the pipeline substrate. As the corrosion depth increases, the pipeline wall thickness continues to decrease, eventually causing pipeline perforation and media leakage, severely impacting the reliability of the system.

[0025] Currently, corrosion control for cold-insulated pipelines still relies solely on visual inspections. These inspections require extensive removal of the pipeline insulation, resulting in a significant workload on-site. Furthermore, the frequent disassembly and reassembly of the insulation layer can damage its structural integrity, weaken its insulation effect, and ultimately exacerbate the corrosion process. Other research focuses on detecting existing corrosion, failing to provide advance assessment and prediction.

[0026] Therefore, there is an urgent need for an assessment and prediction method that can quantitatively analyze corrosion caused by condensate seepage at the ends of cold-insulated pipes, and predict the lifespan of pipes under condensate immersion conditions, thus providing a basis for corrosion management decisions.

[0027] In response, this application provides a method for predicting the corrosion life of insulated pipelines in nuclear power plants, which enables the calculation and prediction of pipeline failure time under condensate immersion conditions, providing technical support for corrosion assessment and management decisions of insulated pipelines.

[0028] See Figure 1 This invention discloses a method for predicting the corrosion life of cold insulation pipes in nuclear power plants, comprising the following steps: Step S10: Obtain the coating failure time of the target pipeline; Step S20: Obtain the pipe failure time of the target pipe; Step S30: Obtain the cumulative corrosion exposure time data of the target pipeline, and calculate the remaining service life of the target pipeline by combining the coating failure time and the pipeline failure time, and output the remaining service life result of the target pipeline.

[0029] The method of the present invention mainly includes the calculation of the coating failure time of the target pipeline (or defined as the calculation of the anti-corrosion coating failure time) and the calculation of the pipeline failure time of the target pipeline (or defined as the calculation of the corrosion rate of the pipeline substrate).

[0030] In particular, if there are discontinuous insulation layers or poor end sealing at irregular locations such as pipe ends and valve interfaces, condensation will quickly form and wet the insulation layer, thus placing the pipe in a high-humidity water environment. Under this environment, the cold wall effect and coating swelling are the core factors for pipe coating failure. Considering the influence of the coating's intrinsic properties, step S10 may include the following steps S11, S12, S13, S14, and S15, which are executed sequentially.

[0031] Further, step S10 includes: Step S11: Obtain basic input parameters, including coating intrinsic performance parameters, pipeline operating condition parameters, insulation material parameters, and environmental parameters; the coating intrinsic performance parameters include coating intrinsic design life t0, cold wall effect proportionality constant k1, wetting expansion effect proportionality constant k2, and coating saturated water absorption rate ω. sat Coating swelling coefficient β, water diffusion coefficient D in the coating, and dry film thickness d of the coating. c The pipeline operating parameters include the ambient-to-pipe wall temperature difference ΔT; the insulation material parameters include the thermal conductivity λ of the insulation layer in a dry state. dry The thermal conductivity λ of the insulation layer under saturated wet state of condensate water wet This environmental parameter includes the relative humidity (RH) of the environment in which the pipeline is located. Step S12: Calculate the acceleration coefficient C of the cold wall effect. cold The acceleration coefficient of the cold wall effect, C cold The calculation formula is: In the formula: C cold k is the acceleration coefficient of the cold wall effect; k1 is the proportionality constant of the cold wall effect, in °C. -1 ΔT represents the ambient temperature difference between the environment and the pipe wall, in °C; λ wet / λ dry The ratio of thermal conductivity before and after the insulation layer is wetted; RH is the ambient relative humidity. Step S13: Calculate the coating swelling acceleration coefficient C swell Coating swelling acceleration coefficient C swell The calculation formula is: In the formula: C swell k1 is the coating swelling acceleration coefficient; k2 is the swelling effect proportionality constant, in seconds. 0.5 ;ω sat β is the saturated water absorption rate of the coating; D is the wetting coefficient of the coating; d is the diffusion coefficient of water in the coating, in µm² / s; c The dry film thickness of the coating is expressed in µm. Step S14: Based on the acceleration coefficient C of the cold wall effect cold With the coating swelling acceleration coefficient C swell Calculate the acceleration term of cold wall-lubrication coupling. Cold wall-lubrication expansion coupling acceleration term The calculation formula is: In the formula: For the cold wall-lubrication coupling acceleration term, C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient; Step S15: Design life based on coating intrinsic design Acceleration term coupled with cold wall-lubrication expansion Calculate the coating failure time Coating failure time The calculation formula is: In the formula: The coating failure time is expressed in years. The intrinsic design life of the coating; For the cold wall-lubrication expansion coupling acceleration term; C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient.

[0032] Furthermore, the purpose of step S11 is to obtain all the basic parameters required for prediction. The basic input parameters are collected and determined, and are divided into four categories. All parameters can be obtained through on-site measurements, standard tests, or supplier test reports.

[0033] Furthermore, the key coefficient calibration method: Calibration of the proportional constant k1 for the cold wall effect: Multiple gradient tests were set up with the constant temperature difference between the environment and the pipe wall as a single variable to test the saturated water diffusion coefficient of the coating under different temperature differences, calculate the diffusion acceleration factor, and obtain the k1 calibration value by fitting. Calibration of the proportionality constant k2 for the inflation effect: using the inflation effect term Multiple gradient tests were set up for a single variable to test the attenuation rate of the low-frequency impedance modulus of the coating, the swelling acceleration factor was calculated, and the k2 calibration value was obtained by fitting. Coupling effect coefficient η calibration: Multiple gradient tests were set up with the dry film thickness of the coating as the single variable. The attenuation rate of the low-frequency impedance modulus of the coating was tested to obtain the actual coupling acceleration factor, based on the formula ln(F real )=1 / η·ln(C cold ·C swell The η calibration value is obtained by fitting the data.

[0034] Furthermore, the purpose of step S12 is to quantify the accelerating effect of the cold wall temperature difference on water molecule penetration after the insulation layer is wetted, and to obtain the coating failure acceleration factor caused by the cold wall effect. The cold wall effect acceleration coefficient C cold ≥1, the larger the value, the stronger the failure acceleration effect of the cold wall effect.

[0035] Furthermore, the purpose of step S13 is to quantify the attenuation effect of the internal stress generated by the water absorption and swelling of the coating on the coating adhesion, and to obtain the failure acceleration factor caused by coating swelling. Coating swelling acceleration factor C swell ≥1, the larger the value, the stronger the accelerating effect of coating swelling failure.

[0036] Furthermore, the purpose of step S14 is to quantify the synergistic coupling acceleration effect of the cold wall effect and the coating swelling. The cold wall effect accelerates the penetration of water molecules into the coating, and the internal stress generated by the coating's water absorption and swelling will cause microcracks and reduced adhesion in the coating, which in turn further accelerates the penetration of water molecules. The two are not simply superimposed, but synergistically accelerated. Therefore, a coupling effect coefficient η is introduced for correction.

[0037] Furthermore, after the coating of the target pipeline fails, the pipeline failure time is calculated. In this method for predicting the corrosion life of cold-insulated pipelines in nuclear power plants, step S20 includes: Step S21: Obtain the pipeline design corrosion allowance C; Step S22: Obtain corrosion rate data and determine the maximum local corrosion rate. ; Step S23: Based on the pipeline design corrosion allowance C and the maximum local corrosion rate Calculate the pipeline failure time of the target pipeline. The failure time of the target pipeline The calculation formula is: In the formula: The pipeline failure time is expressed in years. The corrosion allowance for pipeline design is expressed in mm. This represents the maximum local corrosion rate.

[0038] Furthermore, in step S21, the pipeline design corrosion allowance C, in mm, can be obtained from the design documents.

[0039] Further, in step S22, an in-situ specimen embedding method using the same material as the target pipeline is employed to detect the localized corrosion rate of the pipeline under fully immersion conditions, expressed in mm / a. Specifically, an uncoated bare specimen with the same substrate material as the target pipeline is fabricated and embedded in situ at the most extreme point of complete immersion of the target pipeline, with an embedding period of no less than 6 months. After the specimen is removed, corrosion products are removed according to GB / T 16545 standard, and the pit depth is measured using a laser confocal microscope. The maximum localized corrosion rate obtained during the detection process is recorded. This ensures that the calculation results are the most conservative and conform to the stable maximum corrosion stage working condition after the coating has completely failed.

[0040] Furthermore, in step S23, based on the conservative decision-making principle of nuclear power plants, the trace corrosion during the coating failure development period is ignored, and only the stable corrosion stage lifetime after complete coating failure is calculated. The pipeline design corrosion margin is divided by the stable maximum local corrosion rate to obtain the most conservative pipeline failure time (or defined as the substrate corrosion failure time), specifically: In the formula: The pipeline failure time is expressed in years. The corrosion allowance for pipeline design is expressed in mm. This represents the maximum local corrosion rate.

[0041] Furthermore, in step S30, the remaining service life of the target pipeline is... The calculation formula is: In the formula: The remaining service life of the target pipeline, in years; The coating failure time is expressed in years. t represents the pipeline failure time in years; t represents the cumulative corrosion exposure time of the target pipeline (or the cumulative corrosion exposure duration of the target pipeline) in years.

[0042] Specifically, the cumulative corrosion exposure time (t) of the target pipeline is obtained, in years. Simultaneously, the remaining service life of the target pipeline is calculated based on the coating failure time, the cumulative corrosion exposure time, and the pipeline failure time. .

[0043] In this application, the method of this invention is used to assess corrosion and predict the lifespan of a chilled water pipeline in a nuclear power plant. First, basic parameters such as the intrinsic properties of the coating, pipeline operating conditions, insulation materials, and environment are collected, and then the cold wall effect acceleration factor C is calculated sequentially. cold Coating swelling acceleration coefficient C swell The coating failure time is obtained by coupling the cold wall-wetting expansion acceleration term; then, the pipeline design corrosion margin C is collected to obtain the maximum local corrosion rate. The system calculates the pipeline failure time of the target pipeline; finally, by combining the coating failure time of the target pipeline, the pipeline failure time of the target pipeline, and the cumulative corrosion exposure time of the target pipeline, the remaining service life of the target pipeline is calculated, and the final remaining service life result of the target pipeline is output (or defined as a complete corrosion life prediction result).

[0044] The following example illustrates the corrosion life prediction method for nuclear power plant cold insulation pipes of this application.

[0045] In step S11, the basic parameters are obtained: the coating is an epoxy anti-corrosion coating from a certain manufacturer, t0 = 25 years, β = 1.0, D = 0.5, d c =200, ω sat =3%; chilled water temperature 7℃, ambient temperature 25℃, ΔT=18℃; insulation material is centrifugal glass wool, λ dry =0.035, λ wet =0.3; Ambient RH=65%.

[0046] General Basic Implementation Conditions for Core Coefficient Calibration (1) Sample preparation: The substrate is made of 20# low carbon steel commonly used in nuclear power plant cold insulation pipelines. The sample size is 150mm×70mm×5mm. The surface is sandblasted to Sa2.5 grade with a roughness of 40-80μm. The coating is the same epoxy anti-corrosion coating with a target dry film thickness of 200μm, which is consistent with the coating system of the pipeline on site. Three parallel samples are set for each group of all tests, and the final data is the average value of the parallel samples.

[0047] (2) Core test equipment: high and low temperature alternating damp heat test chamber, electrochemical workstation, electronic analytical balance, thickness gauge, constant temperature circulating cold source system, laser confocal microscope.

[0048] Furthermore, core coefficient calibration: Calibration of the proportionality constant k1 for the cold wall effect (1) Experimental design: fixed boundary conditions λ dry / λ wet =8.57, constant ambient RH=65%, with constant ambient temperature-pipe wall temperature difference ΔT as the single variable, 6 groups of gradient tests were set up.

[0049] (2) Test procedure: The front of the sample faces the test chamber environment side, and the back is tightly attached to the cold plate of the constant temperature cold source to reproduce the real cold wall effect of the pipeline; EIS spectrum is tested once every 24 hours, and the saturated water diffusion coefficient D of the coating is calculated based on Fick's second law. The water diffusion acceleration factor A is calculated with the diffusion coefficient D0 of the ΔT=0℃ reference group as the reference. cold =D / D0.

[0050] (3) Data processing and calibration results With ΔT as the x-coordinate, A cold Using the ordinate as the ordinate, the calculated k1 calibration value for this operating condition is 0.013. The fitted curve is shown in the appendix. Figure 2 .

[0051] Calibration of the proportionality constant k2 for the inflation effect (1) Experimental design: Using the dry film thickness dc of the coating as a single variable, six sets of gradient tests were set up to cover the conventional design thickness range of epoxy coating for cold insulation pipes in nuclear power plants. The core target value is 200μm.

[0052] (2) Experimental procedure: Six groups of samples with different dry film thicknesses were prepared. The actual dry film thickness dc of each group of samples was measured using a thickness gauge. The corresponding swelling effect term M was calculated by substituting the thickness into the formula. All samples were completely immersed in deionized water at a constant temperature of 25°C to simulate the continuous saturation and wetting of the pipeline. Electrochemical impedance spectroscopy (EIS) was performed on each group of samples after immersion for 0, 3, 7, 14, 21, and 28 days, and the coating impedance modulus |Z| at a frequency of 0.01 Hz was recorded. 0·01Hz ; With soaking time t (in days) as the x-axis, lg|Z| 0·01Hz Using the vertical axis as the ordinate, a fitting operation is performed to obtain the absolute value of the slope of the fitted straight line, which is the attenuation rate K of the coating protective performance of this group of samples; taking the attenuation rate K0 of the dry-sealed reference group as the benchmark, the swelling acceleration factor A under different dry film thicknesses is calculated. swell =K / K0.

[0053] (3) Data processing and calibration results With the inflation impact term M as the horizontal axis and the inflation acceleration rate A as the vertical axis... swell A linear fit was performed on the ordinate, and the slope of the fitted line is the k2 calibration value, k2=279. The fitted curve is shown in the appendix. Figure 3 .

[0054] Calibration of coupling effect coefficient η (1) Experimental design: Fixed target operating parameters, with the dry film thickness of the coating as the single variable, set up 5 sets of gradient tests to cover the commonly used coating thickness range of the cold insulation pipes of nuclear power plants, with the core being the target value of 200μm.

[0055] (2) Experimental procedure: Calculate the cold wall acceleration coefficient C cold ; Calculate the inflation acceleration factor C swell ; Simultaneously, under full operating conditions of ΔT=18℃, RH=65%, and complete immersion, the decay rate of coatings with different thicknesses was tested, and the actual coupling acceleration factor F was calculated. real ; Based on the formula ln(F) real )=1 / η·ln(C cold ·C swell Linear fitting is performed to obtain the η calibration value.

[0056] (3) Data processing and calibration results ln(C) cold ·C swell ) is the x-coordinate, ln(F) real Using η as the ordinate, a fitting was performed, with the slope being 1 / η. The calculated η calibration value under the target working condition was 0.60. The fitting curve is shown in the appendix. Figure 4 .

[0057] In step S12: Calculate the acceleration coefficient C of the cold wall effect. cold : In step S13: Calculate the coating swelling acceleration coefficient C. swell : In step S14: Calculate the cold wall-lubrication coupling acceleration term: In step S15: Calculate the coating failure time: Further, the pipeline failure time of the target pipeline is calculated (or defined as the pipeline substrate corrosion failure time).

[0058] Step S21: Obtain the pipeline design corrosion allowance C, where the pipeline corrosion allowance C is 2mm.

[0059] Step S22: Obtain corrosion rate data and determine the maximum local corrosion rate. Among them, a batch of uncoated bare test pieces with the same material as the pipe were made and buried in situ at the point where the pipe was completely wetted for 6 months. After being taken out, they were treated according to the standard and the depth of the corrosion pit was tested. The data are shown in the table below.

[0060] Based on the principle of conservative decision-making, the maximum value is selected. The stable maximum corrosion stage condition after the matching coating has completely failed.

[0061] Step S23: Calculation of the pipeline failure time of the target pipeline. The pipeline failure time is calculated as follows: Year Finally, the remaining service life of the pipeline is calculated: In step S30, the remaining service life of the target pipeline is calculated. This pipeline system has been in operation for 6 years since condensate seepage into the insulation was discovered. Therefore, the remaining service life of the pipeline is: Year In other words, the pipeline system still has a remaining service life of 7.35 years. This information can be used to make decisions regarding management and maintenance measures. These could include conducting comprehensive pipe wall thickness testing and insulation integrity checks, developing specific plans for insulation replacement and pipeline corrosion repair, or even replacing the entire pipeline.

[0062] This method for predicting the corrosion life of insulated pipelines in nuclear power plants is designed for corrosion scenarios involving condensate wetting at the ends of insulated pipelines. It constructs a quantitative calculation model for the entire process from the failure of the anti-corrosion coating to the corrosion failure of the pipeline substrate, enabling early prediction of the remaining service life of the pipeline. This effectively solves the pain point of existing technologies that can only detect after the fact and cannot conduct advance assessments.

[0063] The corrosion life prediction method for nuclear power plant cold insulation pipelines fully considers the accelerated impact of cold wall effect, coating swelling effect, and their synergistic coupling effect on coating failure, and closely matches the actual operating conditions of nuclear power plant cold insulation pipelines; all input parameters can be obtained directly through on-site measurement, standard test or supplier data.

[0064] Based on the life prediction results of the corrosion life prediction method for the cold insulation pipelines in nuclear power plants, the corrosion of the cold insulation pipelines can be controlled in advance without the need for frequent large-scale removal of the insulation layer for offline inspection, which greatly reduces the workload of on-site operation and maintenance. At the same time, it avoids the structural damage and corrosion aggravation caused by repeated disassembly and reassembly of the insulation layer, effectively improving the operational safety and reliability of the chilled water system of the nuclear power plant.

[0065] The corrosion life prediction method for nuclear power plant cold-insulated pipelines can output quantitative data on the remaining life of the pipelines, providing a reliable technical basis for the formulation of maintenance plans, anti-corrosion maintenance decisions, and optimization of replacement cycles for nuclear power plant cold-insulated pipelines.

[0066] This invention also provides a corrosion life prediction system for cold-insulated pipes in nuclear power plants, comprising: The first processing module is used to obtain the coating failure time of the target pipeline; The second processing module is used for the pipeline failure time of the target pipeline; The third processing module is used to acquire the cumulative corrosion exposure time data of the target pipeline, and combine the coating failure time with the pipeline failure time to calculate the remaining service life of the target pipeline, and output the remaining service life result of the target pipeline.

[0067] In some embodiments, the first processing module includes: The first processing unit is used to acquire basic input parameters, including coating intrinsic performance parameters, pipeline operating condition parameters, insulation material parameters, and environmental parameters. The coating intrinsic performance parameters include the coating intrinsic design life t0, cold wall effect proportionality constant k1, wetting expansion effect proportionality constant k2, and coating saturated water absorption rate ω. sat Coating swelling coefficient β, water diffusion coefficient D in the coating, and dry film thickness d of the coating. c The pipeline operating parameters include the ambient-to-pipe wall temperature difference ΔT; the insulation material parameters include the thermal conductivity λ of the insulation layer in a dry state. dry The thermal conductivity λ of the insulation layer under saturated wet state of condensate water wet This environmental parameter includes the relative humidity (RH) of the environment in which the pipeline is located. The second processing unit is used to calculate the acceleration coefficient C of the cold wall effect. cold The acceleration coefficient of the cold wall effect, C cold The calculation formula is: In the formula: C cold k is the acceleration coefficient of the cold wall effect; k1 is the proportionality constant of the cold wall effect, in °C. -1 ΔT represents the ambient temperature difference between the environment and the pipe wall, in °C; λ wet / λ dry The ratio of thermal conductivity before and after the insulation layer is wetted; RH is the ambient relative humidity. The third processing unit is used to calculate the coating swelling acceleration coefficient C. swell Coating swelling acceleration coefficient C swell The calculation formula is: In the formula: C swell k1 is the coating swelling acceleration coefficient; k2 is the swelling effect proportionality constant, in seconds. 0.5 ;ω sat β is the saturated water absorption rate of the coating; D is the wetting coefficient of the coating; d is the diffusion coefficient of water in the coating, in µm² / s;c The dry film thickness of the coating is expressed in µm. The fourth processing unit is used to determine the acceleration coefficient C based on the cold wall effect. cold With the coating swelling acceleration coefficient C swell Calculate the acceleration term of cold wall-lubrication coupling. Cold wall-lubrication expansion coupling acceleration term The calculation formula is: In the formula: For the cold wall-lubrication coupling acceleration term, C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient; The fifth processing unit is used to determine the intrinsic design life of the coating. Acceleration term coupled with cold wall-lubrication expansion Calculate the coating failure time Coating failure time The calculation formula is: In the formula: The coating failure time is expressed in years. The intrinsic design life of the coating; For the cold wall-lubrication expansion coupling acceleration term; C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient.

[0068] In some embodiments, the second processing module includes: The first processing subunit is used to obtain the pipeline design corrosion allowance C; The second processing subunit is used to acquire corrosion rate data and obtain the maximum local corrosion rate. ; The third processing subunit is used to determine the pipeline design corrosion allowance C and the maximum local corrosion rate. Calculate the pipeline failure time of the target pipeline. The failure time of the target pipeline The calculation formula is: In the formula: The pipeline failure time is expressed in years. The corrosion allowance for pipeline design is expressed in mm. This represents the maximum local corrosion rate.

[0069] In some embodiments, the third processing module is configured to calculate the remaining service life of the target pipeline according to the formula for calculating the remaining service life of the target pipeline. Among them, the remaining service life of the target pipeline The calculation formula is: In the formula: The remaining service life of the target pipeline, in years; The coating failure time is expressed in years. t represents the pipeline failure time in years; t represents the cumulative corrosion exposure time of the target pipeline (or the cumulative corrosion exposure duration of the target pipeline) in years.

[0070] This corrosion life prediction system for nuclear power plant cold-insulated pipelines is designed for corrosion scenarios involving condensate wetting at the ends of cold-insulated pipelines in nuclear power plants. It constructs a quantitative calculation model for the entire process from the failure of the anti-corrosion coating to the corrosion failure of the pipeline substrate, enabling early prediction of the remaining service life of the pipeline. This effectively solves the pain point of existing technologies that can only detect after the fact and cannot conduct advance assessments.

[0071] The corrosion life prediction system for nuclear power plant cold insulation pipelines fully considers the accelerated impact of cold wall effect, coating swelling effect, and their synergistic coupling effect on coating failure, and closely matches the actual operating conditions of nuclear power plant cold insulation pipelines; all input parameters can be obtained directly through on-site measurement, standard test or supplier data.

[0072] Based on the life prediction results of the corrosion life prediction system for the cold insulation pipelines in nuclear power plants, it is possible to achieve advanced control of corrosion of the cold insulation pipelines, eliminating the need for frequent large-scale removal of the insulation layer for offline inspection, significantly reducing the workload of on-site operation and maintenance, and avoiding structural damage and corrosion aggravation caused by repeated disassembly and reassembly of the insulation layer, thus effectively improving the operational safety and reliability of the chilled water system in nuclear power plants.

[0073] The corrosion life prediction system for nuclear power plant cold-insulated pipelines can output quantitative data on the remaining life of the pipelines, providing a reliable technical basis for the formulation of maintenance plans, anti-corrosion maintenance decisions, and optimization of replacement cycles for nuclear power plant cold-insulated pipelines.

[0074] The present invention also provides a storage medium storing a computer program that, when executed, implements the steps of the method for predicting the corrosion life of nuclear power plant cold insulation pipes according to any of the above embodiments.

[0075] The present invention also provides a computer device including a memory and a processor, wherein the memory stores a computer program that can run on the processor, and the processor executes the computer program to implement the steps of the method for predicting the corrosion life of nuclear power plant cold insulation pipes according to any of the above embodiments.

[0076] It should be noted that the various technical solutions described in this invention can be implemented using digital circuits, or using computer hardware, firmware, software, and combinations thereof. They can also be implemented through computer program products. These computer programs are embedded in information carriers (e.g., machine-readable storage devices or transmitted signals), and can be executed by or used to control the operation of data processing devices, such as programmable processors, computers, or multiple computers. Computer programs, as described above, can be written in any form of programming language, including assembly or interpreted languages, and can be used in any form, including, for example, standalone programs, or modules, components, subroutines, or other units suitable for use in a computing environment. Computer programs can be used to run on one or more computers, which can be located in the same location or distributed across multiple locations and interconnected through a communication network.

[0077] The method steps can be executed by one or more programmable processors, which run computer programs, manipulate input data, and generate output data to perform their functions. The method steps can also be executed by dedicated logic circuitry, and the apparatus can also be implemented using dedicated logic circuitry, such as an FPGA (Field-Programmable Gate Array) or an ASIC (Application-Specific Integrated Circuit).

[0078] Processors suitable for executing computer programs include, for example, general-purpose and special-purpose microprocessors, and any one or more processors of any kind of digital computer. Typically, a processor receives instructions and data from read-only memory or random access memory, or both. Computer components include at least one processor for executing instructions and one or more storage devices for storing instructions and data. Typically, a computer may also include one or more mass storage devices for storing data, or be operatively connected to one or more mass storage devices for storing data to receive data from or transmit data to them; said mass storage devices are, for example, magnetic disks, magneto-optical disks, or optical disks. Information carriers suitable for containing computer program instructions and data include all forms of non-volatile memory, including semiconductor storage devices such as EPROMs, EEPROMs, and flash memory; magnetic disks such as internal hard disks or removable disks; magneto-optical disks; and CD-ROMs and DVD-ROMs. Processors and memory may be implemented by or incorporated into special-purpose logic circuitry.

[0079] This invention can also be implemented via a computer system, which includes back-end components such as a data server, or middleware such as an application server, or front-end components such as a client computer with a graphical user interface or a web browser (through which users can interactively participate in implementing this invention), or any combination of the aforementioned back-end, middleware, or front-end components. These components can be interconnected via any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include local area networks (LANs) and wide area networks (WANs), such as the Internet.

[0080] It is understood that the above embodiments only illustrate preferred embodiments of the present invention, and their descriptions are relatively specific and detailed, but they should not be construed as limiting the scope of the present invention. It should be noted that those skilled in the art can freely combine the above technical features without departing from the concept of the present invention, and can also make several modifications and improvements, all of which fall within the protection scope of the present invention. Therefore, all equivalent transformations and modifications made with respect to the scope of the claims of the present invention should fall within the scope of the claims of the present invention.

Claims

1. A method for predicting the corrosion life of cold-insulated pipes in nuclear power plants, characterized in that, Includes the following steps: step S10: Obtain the coating failure time of the target pipeline; Step S20: Obtain the pipe failure time of the target pipe; Step S30: Obtain the cumulative corrosion exposure time data of the target pipeline, and calculate the remaining service life of the target pipeline by combining the coating failure time and the pipeline failure time.

2. The method for predicting the corrosion life of cold-insulated pipelines in nuclear power plants according to claim 1, characterized in that, Step S10 includes: Step S11: Obtain basic input parameters, including coating intrinsic performance parameters, pipeline operating condition parameters, insulation material parameters, and environmental parameters; the coating intrinsic performance parameters include coating intrinsic design life t0, cold wall effect proportionality constant k1, wetting expansion effect proportionality constant k2, and coating saturated water absorption rate ω. sat Coating swelling coefficient β, water diffusion coefficient D in the coating, and dry film thickness d of the coating. c The pipeline operating parameters include the ambient-pipe wall temperature difference ΔT; the insulation material parameters include the thermal conductivity λ of the insulation layer in a dry state. dry The thermal conductivity λ of the insulation layer under saturated wet state of condensate water wet The environmental parameters include the relative humidity (RH) of the environment in which the pipeline is located. Step S12: Calculate the acceleration coefficient C of the cold wall effect. cold The acceleration coefficient of the cold wall effect, C cold The calculation formula is: In the formula: C cold k is the acceleration coefficient of the cold wall effect; k1 is the proportionality constant of the cold wall effect, in °C. -1 ΔT represents the ambient temperature difference between the environment and the pipe wall, in °C; λ wet / λ dry The ratio of thermal conductivity before and after the insulation layer is wetted; RH is the ambient relative humidity. Step S13: Calculate the coating swelling acceleration coefficient C swell Coating swelling acceleration coefficient C swell The calculation formula is: In the formula: C swell k1 is the coating swelling acceleration coefficient; k2 is the swelling effect proportionality constant, in seconds. 0.5 ;ω sat β is the saturated water absorption rate of the coating; D is the wetting coefficient of the coating; d is the diffusion coefficient of water in the coating, in µm² / s; c The dry film thickness of the coating is expressed in µm. Step S14: Based on the acceleration coefficient C of the cold wall effect cold With the coating swelling acceleration coefficient C swell Calculate the acceleration term of cold wall-lubrication coupling. Cold wall-lubrication expansion coupling acceleration term The calculation formula is: In the formula: For the cold wall-lubrication coupling acceleration term, C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient; Step S15: Design life based on coating intrinsic design Acceleration term coupled with cold wall-lubrication expansion Calculate the coating failure time Coating failure time The calculation formula is: In the formula: The coating failure time is expressed in years. The intrinsic design life of the coating; For the cold wall-lubrication coupling acceleration term; C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient.

3. The method for predicting the corrosion life of cold-insulated pipes in nuclear power plants according to claim 2, characterized in that, Step S20 includes: Step S21: Obtain the pipeline design corrosion allowance C; Step S22: Obtain corrosion rate data and determine the maximum local corrosion rate. ; Step S23: Based on the pipeline design corrosion allowance C and the maximum local corrosion rate Calculate the pipeline failure time of the target pipeline. The failure time of the target pipeline The calculation formula is: In the formula: The pipeline failure time is expressed in years. The corrosion allowance for pipeline design is expressed in mm. This represents the maximum local corrosion rate.

4. The method for predicting the corrosion life of cold-insulated pipes in nuclear power plants according to claim 3, characterized in that, In step S30, the remaining service life of the target pipeline is determined. The calculation formula is: In the formula: The remaining service life of the target pipeline, in years; The coating failure time is expressed in years. t represents the pipeline failure time in years; t represents the cumulative corrosion exposure time of the target pipeline in years.

5. A corrosion life prediction system for cold-insulated pipes in nuclear power plants, characterized in that, include: The first processing module is used to obtain the coating failure time of the target pipeline; The second processing module is used for the pipeline failure time of the target pipeline; The third processing module is used to acquire the cumulative corrosion exposure time data of the target pipeline, and calculate the remaining service life of the target pipeline by combining the coating failure time and the pipeline failure time.

6. The corrosion life prediction system for nuclear power plant cold insulation pipelines according to claim 5, characterized in that, The first processing module includes: The first processing unit is used to acquire basic input parameters, including coating intrinsic performance parameters, pipeline operating condition parameters, insulation material parameters, and environmental parameters. The coating intrinsic performance parameters include coating intrinsic design life t0, cold wall effect proportionality constant k1, wetting expansion effect proportionality constant k2, and coating saturated water absorption rate ω. sat Coating swelling coefficient β, water diffusion coefficient D in the coating, and dry film thickness d of the coating. c The pipeline operating parameters include the ambient-pipe wall temperature difference ΔT; the insulation material parameters include the thermal conductivity λ of the insulation layer in a dry state. dry The thermal conductivity λ of the insulation layer under saturated wet state of condensate water wet The environmental parameters include the relative humidity (RH) of the environment in which the pipeline is located. The second processing unit is used to calculate the acceleration coefficient C of the cold wall effect. cold The acceleration coefficient of the cold wall effect, C cold The calculation formula is: In the formula: C cold k is the acceleration coefficient of the cold wall effect; k1 is the proportionality constant of the cold wall effect, in °C. -1 ΔT represents the ambient temperature difference between the environment and the pipe wall, in °C; λ wet / λ dry The ratio of thermal conductivity before and after the insulation layer is wetted; RH is the ambient relative humidity. The third processing unit is used to calculate the coating swelling acceleration coefficient C. swell Coating swelling acceleration coefficient C swell The calculation formula is: In the formula: C swell k1 is the coating swelling acceleration coefficient; k2 is the swelling effect proportionality constant, in seconds. 0.5 ;ω sat β is the saturated water absorption rate of the coating; D is the wetting coefficient of the coating; d is the diffusion coefficient of water in the coating, in µm² / s; c The dry film thickness of the coating is expressed in µm. The fourth processing unit is used to determine the acceleration coefficient C based on the cold wall effect. cold With the coating swelling acceleration coefficient C swell Calculate the acceleration term of cold wall-lubrication coupling. Cold wall-lubrication expansion coupling acceleration term The calculation formula is: In the formula: For the cold wall-lubrication coupling acceleration term, C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient; The fifth processing unit is used to determine the intrinsic design life of the coating. Acceleration term coupled with cold wall-lubrication expansion Calculate the coating failure time Coating failure time The calculation formula is: In the formula: The coating failure time is expressed in years. The intrinsic design life of the coating; For the cold wall-lubrication coupling acceleration term; C cold C is the acceleration factor for the cold wall effect. swell η is the coating swelling acceleration coefficient; η is the coupling effect coefficient.

7. The corrosion life prediction system for nuclear power plant cold insulation pipelines according to claim 6, characterized in that, The second processing module includes: The first processing subunit is used to obtain the pipeline design corrosion allowance C; The second processing subunit is used to acquire corrosion rate data and obtain the maximum local corrosion rate. ; The third processing subunit is used to determine the pipeline design corrosion allowance C and the maximum local corrosion rate. Calculate the pipeline failure time of the target pipeline. The failure time of the target pipeline The calculation formula is: In the formula: The pipeline failure time is expressed in years. The corrosion allowance for pipeline design is expressed in mm. This represents the maximum local corrosion rate.

8. The corrosion life prediction system for nuclear power plant cold insulation pipelines according to claim 7, characterized in that, The third processing module is used to determine the remaining service life of the target pipeline. The calculation formula calculates the remaining service life of the target pipeline. Among them, the remaining service life of the target pipeline The calculation formula is: In the formula: The remaining service life of the target pipeline, in years; The coating failure time is expressed in years. t represents the pipeline failure time in years; t represents the cumulative corrosion exposure time of the target pipeline in years.

9. A storage medium, characterized in that, The storage medium stores a computer program, which, when executed, implements the steps of the method for predicting the corrosion life of cold-insulated pipes in nuclear power plants according to any one of claims 1 to 4.

10. A computer device comprising a memory and a processor, wherein the memory stores a computer program executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the method for predicting the corrosion life of nuclear power plant cold insulation pipes as described in any one of claims 1 to 4.

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