CN114383998A - Pipeline corrosion monitoring method and system and electronic equipment - Google Patents

Abstract

The invention relates to the technical field of pipeline monitoring, and in particular to a method, system and electronic device for monitoring pipeline corrosion. The method includes acquiring a first magnetic field gradient modulus and a second magnetic field gradient modulus, and determining and the second magnetic field gradient modulus to determine the damage level index of the second preset position, and then determine the difference between the current defect stress value of the second preset position and the yield strength corresponding to the material of the pipeline to be monitored according to the damage level index The current ratio of , and the pre-warning based on the current ratio and the preset pre-warning strategy can effectively evaluate the stress safety state of the second preset position of the pipeline to be monitored, and the accuracy of the test results is high.

Description

Method, system and electronic device for monitoring pipeline corrosion

technical field

The invention relates to the technical field of pipeline monitoring, and in particular, to a method, system and electronic equipment for monitoring pipeline corrosion.

Background technique

The surface oil and gas pipelines in oilfield stations mainly suffer from internal corrosion, which is mainly caused by electrochemical corrosion caused by the corrosiveness of the transport medium. The main corrosive components in the corrosion of crude oil pipelines are water and various chemical additives. The purified crude oil in the long-distance pipeline is dehydrated, and the content of corrosive components is generally very small, and the internal corrosion is very slight. However, due to the untreated crude oil containing water, impurities and chemicals, the oilfield gathering and transportation pipelines have serious internal corrosion. The internal corrosion of natural gas pipelines is also relatively serious. Associated gas produced in oilfields and gas wells contain corrosive components such as water, hydrogen sulfide, and carbon dioxide. Electrochemical corrosion is prone to occur during the gas transmission process, causing serious corrosion of the inner wall of the pipeline or even perforation and leakage, resulting in Major safety incident.

The ultrasonic guided wave detection of pipeline corrosion is an important pipeline detection technology. The ultrasonic guided wave has the advantages of long-distance transmission (the propagation distance can reach 160m on the open pipe in the oil field), and the speed of data collection is fast. Locations such as field and penetration corrosion have good application prospects. At present, some mechanisms and characteristics of guided waves are still being explored, but the detection results are authentic and reliable, and they have been applied to corrosion detection of domestic oilfield pipelines and urban buried gas pipelines.

At present, the ultrasonic guided wave technology is used for defect monitoring, and the main steps are:

First, excavate the corroded pipe section to be monitored, peel off the anti-corrosion layer and paint layer, and install the sensor.

Then, the sensor sends out a beam of ultrasonic pulse wave, which fills the thickness of the pipe wall and propagates far along the axis of the pipe. When a defect is encountered during the transmission of the guided wave, the defect has a certain reflection area on the radial section due to the defect. , a defect echo is generated. When the defect echo is received by the probe, the defect position can be determined.

Finally, the echo signal detected by the ultrasonic guided wave is the pulse echo signal. During the detection, the flange or pipe end face echo is used as the reference wave. The echo signal that appears between the initial pulse and the reference wave is the defect echo signal. Determine the location and size of the defect according to the amplitude of the echo and the length from the reference wave.

But the above-mentioned prior art has the following defects:

1) The root cause of the pipeline integrity problem is that the local stress of the pipeline wall defect exceeds the bearing capacity of the pipeline material, resulting in leakage and perforation of the pipeline. Therefore, the integrity decision mainly considers the local stress value of the pipe wall defect. The existing ultrasonic guided wave monitoring technology measures the geometric size of the pipeline defect, and then calculates the local stress value at the defect according to relevant standards such as ASME B31G. However, the stress value calculated according to the geometric size of the defect often has a large deviation from the real value. , it is impossible to effectively evaluate the safety status of the corroded pipe section;

2) When the ultrasonic guided wave monitoring technology is used to monitor the corrosion defects in the pipeline of the station, the solid impurities accumulated at the defect positions on the inner wall of the pipe will interfere with the ultrasonic guided wave signal, causing the test results to deviate from the actual situation. Cumulatively, the accuracy of the test results decreases.

SUMMARY OF THE INVENTION

The technical problem to be solved by the present invention is to provide a method and system for monitoring pipeline corrosion in view of the deficiencies of the prior art.

The technical scheme of a pipeline corrosion monitoring method of the present invention is as follows:

Obtain the first preset position on the axis line of the reference pipeline, and the first magnetic field gradient modulus when measuring the height in the preset unit;

Obtain a second preset position on the axis line of the pipeline to be monitored, the second magnetic field gradient modulus at the preset measurement height, and according to the first magnetic field gradient modulus and the second magnetic field gradient modulus, determining the damage level index of the second preset position, wherein the reference pipeline has the same specifications as the pipeline to be monitored;

Determine the current ratio between the current defect stress value of the second preset position and the yield strength corresponding to the material of the pipeline to be monitored according to the damage level index;

Early warning is performed according to the current ratio and a preset early warning strategy.

The beneficial effects of the method for monitoring pipeline corrosion of the present invention are as follows:

Obtaining and according to the first magnetic field gradient modulus corresponding to the reference pipeline, the second magnetic field gradient modulus can be automatically converted into the current defect stress value of the second preset position of the pipeline to be monitored and the yield corresponding to the material of the pipeline to be monitored in real time. The ratio between the strengths can effectively evaluate the stress safety state of the second preset position of the pipeline to be monitored. Moreover, it is the change of the magnetic signal of the corroded pipe section caused by the local stress change caused by the pipe wall defect of the pipeline to be monitored. Therefore, the impurities on the inner wall of the pipeline to be monitored will not cause the local stress change at the defect, so it will not affect the test accuracy. It greatly improves the accuracy and reliability of the test results.

On the basis of the above scheme, the method for monitoring pipeline corrosion of the present invention can also be improved as follows.

Further, the process of obtaining the first magnetic field gradient modulus includes:

The first preset position on the axis line of the reference pipeline is collected by the magnetic sensor, and the initial magnetic field data when the height is measured in a preset unit;

y分量

和z分量

Obtained from the initial magnetic field data: the x component of the magnetic field gradient perpendicular to the axis of the reference pipe

y-component

and the z component

According to the first formula, the first magnetic field gradient modulus G' is calculated,

Further, the process of determining the damage level index of the second preset position includes:

其中，G_M＝Gf(h)，

A表示修正系数，G 表示所述第二磁场梯度模量，h表示所述预设测量高度。The damage level index F of the second preset position is calculated by using the second formula, and the second formula is:

where G _M =Gf(h),

A represents a correction coefficient, G represents the gradient modulus of the second magnetic field, and h represents the preset measurement height.

Further, the process of determining the current ratio includes:

The third formula is used to determine and calculate the current ratio, and the third formula is σ _d /σ _s =(-283.1F ^1.08 +383.3), where σ _d represents the current defect stress value at the second preset position, σ _s represents the yield strength corresponding to the material of the pipeline to be monitored.

Further, it also includes:

Obtain and fit the functional relationship between the propagation factor and the measurement height according to the third magnetic field gradient moduli at different measurement heights at the third preset position on the axis of the reference pipeline.

Further, the functional relationship between the fitting propagation factor and the measured height includes:

G″表示任 一第三磁场梯度模量；Calculate the propagation factor f corresponding to any third magnetic field gradient modulus according to the fourth formula until the propagation factor corresponding to each third magnetic field gradient modulus is obtained, and the fourth formula is:

G" represents any third magnetic field gradient modulus;

H表示测量高度，所述第 五公式为

其中，A₁、A₂、B₁和B₂均为系数。Determined according to the fifth formula: A ₁ =a ₁ , A ₂ =a ₂ , B ₁ =b ₁ , B ₂ =b ₂ , the functional relationship between the propagation factor and the measurement height is obtained as:

H represents the measurement height, and the fifth formula is

Among them, A ₁ , A ₂ , B ₁ and B ₂ are all coefficients.

The technical scheme of a pipeline corrosion monitoring system of the present invention is as follows:

including a first acquisition module, a second acquisition module, a calculation module and an early warning module;

The first acquisition module is used for: acquiring the first preset position on the axis of the reference pipeline, the first magnetic field gradient modulus when measuring the height in preset units;

The second acquisition module is used for: acquiring the second preset position on the axis of the pipeline to be monitored, the second magnetic field gradient modulus at the preset measurement height, and obtaining the second magnetic field gradient modulus according to the first magnetic field gradient modulus and the The second magnetic field gradient modulus determines the damage level index of the second preset position, wherein the reference pipeline has the same specifications as the pipeline to be monitored;

The calculation module is used to: determine the current ratio between the current defect stress value of the second preset position and the yield strength corresponding to the material of the pipeline to be monitored according to the damage level index;

The early-warning module is used for: performing early-warning according to the current ratio and a preset early-warning strategy.

The beneficial effects of a pipeline corrosion monitoring system of the present invention are as follows:

Obtaining and according to the first magnetic field gradient modulus corresponding to the reference pipeline, the second magnetic field gradient modulus can be automatically converted into the current defect stress value of the second preset position of the pipeline to be monitored and the yield corresponding to the material of the pipeline to be monitored in real time. The ratio between the strengths can effectively evaluate the stress safety state of the second preset position of the pipeline to be monitored. Moreover, it is the change of the magnetic signal of the corroded pipe section caused by the local stress change caused by the pipe wall defect of the pipeline to be monitored. Therefore, the impurities on the inner wall of the pipeline to be monitored will not cause the local stress change at the defect, so it will not affect the test accuracy. It greatly improves the accuracy and reliability of the test results.

On the basis of the above scheme, the monitoring system for pipeline corrosion of the present invention can also be improved as follows.

Further, the first acquisition module is specifically used for:

The first preset position on the axis line of the reference pipeline is collected by the magnetic sensor, and the initial magnetic field data when the height is measured in a preset unit;

y分量

和z分量

Obtained from the initial magnetic field data: the x component of the magnetic field gradient perpendicular to the axis of the reference pipe

y-component

and the z component

According to the first formula, the first magnetic field gradient modulus G' is calculated,

Further, the second acquisition module is specifically used for:

其中，G_M＝Gf(h)，

A表示修正系数，G 表示所述第二磁场梯度模量，h表示所述预设测量高度。The damage level index F of the second preset position is calculated by using the second formula, and the second formula is:

where G _M =Gf(h),

A represents a correction coefficient, G represents the gradient modulus of the second magnetic field, and h represents the preset measurement height.

Further, the computing module is specifically used for:

The third formula is used to determine and calculate the current ratio, and the third formula is σ _d /σ _s =(-283.1F ^1.08 +383.3), where σ _d represents the current defect stress value at the second preset position, σ _s represents the yield strength corresponding to the material of the pipeline to be monitored.

Further, it also includes a third acquisition module;

The third acquisition module is used for: acquiring and fitting the functional relationship between the propagation factor and the measurement height according to the third magnetic field gradient moduli at different measurement heights at the third preset position on the axis of the reference pipeline .

Further, the third acquisition module is specifically used for:

G″表示任 一第三磁场梯度模量；Calculate the propagation factor f corresponding to any third magnetic field gradient modulus according to the fourth formula until the propagation factor corresponding to each third magnetic field gradient modulus is obtained, and the fourth formula is:

G" represents any third magnetic field gradient modulus;

H表示测量高度，所述第 五公式为

其中，A₁、A₂、B₁和B₂均为系数。Determined according to the fifth formula: A ₁ =a ₁ , A ₂ =a ₂ , B ₁ =b ₁ , B ₂ =b ₂ , the functional relationship between the propagation factor and the measurement height is obtained as:

H represents the measurement height, and the fifth formula is

Among them, A ₁ , A ₂ , B ₁ and B ₂ are all coefficients.

The technical scheme of a kind of electronic equipment of the present invention is as follows:

It includes a memory, a processor and a program stored on the memory and running on the processor, and when the processor executes the program, the steps of the method for monitoring pipeline corrosion as described in any of the above are implemented .

Description of drawings

1 is a schematic flowchart of a method for monitoring pipeline corrosion according to an embodiment of the present invention;

Fig. 2 is the measurement schematic diagram that obtains the first magnetic field gradient modulus;

Figure 3 is a schematic diagram of the simulation calculation results of local stress at the defect;

FIG. 4 is a schematic structural diagram of a pipeline corrosion monitoring system according to an embodiment of the present invention.

Detailed ways

As shown in FIG. 1 , a method for monitoring pipeline corrosion according to an embodiment of the present invention includes the following steps:

S1, obtain the first preset position on the axis line of the reference pipeline, the first magnetic field gradient modulus when measuring the height in the preset unit;

Among them, the reference pipeline can be understood as a standard pipeline that meets the standards of industrial application and is free from any corrosion and other damages and defects;

The first preset position may be an artificially selected position, or, any position on the axis of the reference pipeline, since the reference pipeline has not been subjected to any corrosion and other damages and defects, therefore, when the first preset position is the reference At different positions on the axis line of the pipeline, the deviation between the obtained first magnetic field gradient moduli in the preset unit measurement height is very small and can be considered to be equal.

Wherein, the preset unit measurement height may be 1 meter or 1 decimeter, etc., which can also be confirmed according to the actual situation, and the preset unit measurement height refers to the vertical distance from the axis line of the reference pipe. As shown in Figure 2, the length of the reference pipeline can be set according to the actual situation, such as 1 meter or 2 meters.

S2. Obtain the second preset position on the axis of the pipeline to be monitored, the second magnetic field gradient modulus at the preset measurement height, and determine the first magnetic field gradient modulus and the second magnetic field gradient modulus according to the first magnetic field gradient modulus and the second magnetic field gradient modulus. 2. The damage level index of the preset position, wherein the reference pipeline has the same specifications as the pipeline to be monitored;

Wherein, the second preset position can be understood as: any position on the axis of the pipeline to be monitored, or a plurality of easily corroded positions can be determined according to the historical data of the pipeline to be monitored, and any easily corroded position can be used as The second preset position.

The specification of the reference pipeline and the pipeline to be monitored is the same specifically refers to: the reference pipeline and the pipeline to be monitored are of the same material, diameter and wall thickness.

The preset measurement height is a known quantity, and the damage level index of the pipeline to be monitored can be determined according to the first magnetic field gradient modulus and the second magnetic field gradient modulus, and the preset measurement height refers to the distance from the pipeline to be monitored. The vertical distance between the axis lines.

S3, determine the current ratio between the current defect stress value of the second preset position and the yield strength corresponding to the material of the pipeline to be monitored according to the damage level index;

For example, if the material of the pipeline to be monitored is No. 45 steel, the yield strength corresponding to No. 45 steel is selected.

S4. Perform an early warning according to the current ratio and a preset early warning strategy. Among them, the preset early warning strategy is:

1) When the ratio is 40%, it is the first-level response warning value. When the current ratio between the current defect stress value of the pipeline to be monitored and the yield strength corresponding to the material of the pipeline to be monitored exceeds the first-level response warning value, it means that the Focus on monitoring the second preset position of the pipeline to be monitored, and issue sound and light warnings or remind maintenance personnel in other forms;

2) When the ratio is 60%, it is the second-level response warning value. When the current ratio between the current defect stress value of the pipeline to be monitored and the yield strength corresponding to the material of the pipeline to be monitored exceeds the second-level response warning value, it means that Under certain conditions, the second preset position of the pipeline to be monitored can be repaired, and sound and light warnings can be issued accordingly or reminders to maintenance personnel in other forms;

3) When the ratio is 80%, it is the third-level response warning value. When the current ratio between the current defect stress value of the pipeline to be monitored and the yield strength corresponding to the material of the pipeline to be monitored exceeds the third-level response warning value, it indicates that the Immediately stop the pipeline to be monitored to replace or maintain the second preset position, and send out sound and light warnings or remind maintenance personnel in other forms.

Obtaining and according to the first magnetic field gradient modulus corresponding to the reference pipeline, the second magnetic field gradient modulus can be automatically converted into the current defect stress value of the second preset position of the pipeline to be monitored and the yield corresponding to the material of the pipeline to be monitored in real time. The ratio between the strengths can effectively evaluate the stress safety state of the second preset position of the pipeline to be monitored. Moreover, it is the change of the magnetic signal of the corroded pipe section caused by the local stress change caused by the pipe wall defect of the pipeline to be monitored. Therefore, the impurities on the inner wall of the pipeline to be monitored will not cause the local stress change at the defect, so it will not affect the test accuracy. It greatly improves the accuracy and reliability of the test results.

Optionally, in the above technical solution, the process of obtaining the first magnetic field gradient modulus includes:

S10, collect the first preset position on the axis line of the reference pipeline through the magnetic sensor, and measure the initial magnetic field data at the preset unit height;

y分量

和z分量

S11. Acquire according to the initial magnetic field data: the x component of the magnetic field gradient perpendicular to the axis of the reference pipeline

y-component

and the z component

S12, according to the first formula, calculate the first magnetic field gradient modulus G',

Specifically, it can be achieved in the following ways:

1) Using only one magnetic sensor such as a Hall sensor or a fluxgate magnetometer, collect the first preset position on the axis of the reference pipe, and measure the initial magnetic field data in the preset unit of height, and then execute S11 and S12, the first magnetic field gradient modulus G' is obtained by calculation;

和

2) Use at least two magnetic sensors to collect multiple magnetic field data respectively, that is, at this time, the initial magnetic field data includes multiple magnetic field data, and according to each magnetic field data, calculate the x component, y component and z component of the magnetic field gradient corresponding to each magnetic sensor components, and take the average to get the above

and

其中，i表示磁感应强度的x、y、 z方向，B_i1表示第一个磁力传感器在i方向的磁感应强度，B_i2表示第二个传 感器在i方向的磁感应强度，单位均可为nT或mT等，l表示磁力传感器的 长度，单位为m。In another embodiment,

Among them, i represents the x, y, and z directions of the magnetic induction intensity, B _i1 represents the magnetic induction intensity of the first magnetic sensor in the i direction, B _i2 represents the magnetic induction intensity of the second sensor in the i direction, and the unit can be nT or mT etc., l represents the length of the magnetic sensor in m.

Among them, the magnetic sensor, that is, the magnetic sensor, is installed as follows:

A concrete base is poured on the ground just above the buried corrosion pipe section to be monitored, that is, the pipeline to be monitored. A sealed carbon fiber protective box is fixed on the base, and the magnetic sensor, that is, the magnetic sensor, is placed in the protective box and anchored through the specially set screw holes at the bottom. Sensor to prevent external damage. Based on the magneto-mechanical effect, the magnetic sensor, that is, the magnetic sensor, can collect the weak magnetic field signal of the buried pipeline on the ground, so as to analyze the stress safety state of the corroded pipe section.

The second magnetic sensor installed in the axial direction 3m from the monitoring pipe section according to the above method is the compensation magnetic sensor, which is used to monitor the change of the sensor test value caused by external factors such as temperature and humidity. Therefore, the influence of the change of external environmental conditions on the identification of the stress state of pipeline defects is eliminated.

The process of monitoring data transfer is as follows:

The above two magnetic sensors are connected to the data acquisition system through the communication data line. After connecting the data line, the protective shell is sealed with sealant, which is waterproof and moisture-proof and prolongs the service life of the sensor. The wireless transmission module of the data acquisition system transmits the monitoring data to the cloud platform, and the user logs in the monitoring software to access the cloud platform to view the monitoring data in real time. The monitoring system is powered by the power supply equipment in the station yard.

Wherein, the specific process of obtaining the second preset position on the axis line of the pipeline to be monitored, and the second magnetic field gradient modulus at the preset measurement height, refer to the above-mentioned S10 to S12, and will not be repeated here.

In another embodiment, when the preset unit measurement height is 1 meter, the G' calculated at this time can be denoted as G ₁ , that is, G ₁ represents: referring to the first preset on the axis of the pipeline Set the position and measure the first magnetic field gradient modulus in the preset unit, which can be used in subsequent calculations.

At present, the corrosion monitoring of ultrasonic guided wave technology still has the following problems:

When the ultrasonic guided wave technology is used to monitor the internal corrosion defects of the buried pipeline in the station, the front-end sensor is buried in the ground and lacks effective protection measures, which is prone to erosion in the soil environment and shortens its service life. At the same time, the sensors buried in the ground are difficult to be inspected and maintained, and it is impossible to grasp the integrity of the sensors in real time.

In the present application, the monitoring sensor, ie, the magnetic sensor, is installed on the ground, which is convenient for inspection and maintenance; and a sealed carbon fiber casing can be provided on the magnetic sensor, which is waterproof, moisture-proof, and damage-proof by external force, so as to prolong the service life.

Optionally, in the above technical solution, in S2, the process of determining the damage level index of the second preset position includes:

其中，G_M＝Gf(h)，

A表示修正系数，G表示 第二磁场梯度模量，h表示预设测量高度。S20, using the second formula to calculate the damage level index F of the second preset position, and the second formula is:

where G _M =Gf(h),

A represents the correction coefficient, G represents the second magnetic field gradient modulus, and h represents the preset measurement height.

Wherein, the value of A can be determined according to experience, that is, the correction coefficient can be an empirical value, and the value of A can also be calculated according to the following methods, specifically:

According to the historical data of internal corrosion defect detection of buried pipelines in natural gas stations, that is, according to the historical data of internal corrosion defect detection of pipelines to be monitored, select relatively severe corrosion sections (corrosion depth>20%T, T is the wall thickness of the pipeline) for dynamic real-time detection monitor.

中的F，由于根 据待监测管道的内腐蚀缺陷检测历史数据能够计算出当前的管道损伤程度 的度量值，带入

中，能够计算出A的值。Collect the basic data of the pipeline to be monitored, mainly including the material of the pipeline to be monitored, pipeline specifications, operating conditions, as well as the length and buried depth of the pipeline to be monitored. Combined with the historical data of the internal corrosion defect detection of the pipeline to be monitored, the finite element analysis software ANSYS is used to simulate and calculate the local stress value at the corrosion defect of the monitored pipe section under operating conditions, as shown in Figure 3, and then the corresponding pipeline damage is obtained according to the third formula. Grade index, replace it according to the damage grade index of the pipeline

In F, because the measurement value of the current pipeline damage degree can be calculated according to the historical data of the internal corrosion defect detection of the pipeline to be monitored, it is brought into

, the value of A can be calculated.

Among them, G _M represents a measure of the damage degree of the pipeline to be monitored.

Optionally, in the above technical solution, in S3, the process of determining the current ratio includes:

S30. Use the third formula to determine and calculate the current ratio. The third formula is σ _d /σ _s =(-283.1F ^1.08 +383.3), where σ _d represents the current defect stress value at the second preset position, and σ _s represents the to-be-to-be-defect stress value. Monitor the yield strength of the pipe material.

Optionally, in the above technical solution, it also includes:

S5, obtain and refer to the third magnetic field gradient modulus of the third preset position on the axis line of the reference pipeline at different measurement heights, and fit the functional relationship between the propagation factor and the measurement height;

The third preset position may be an artificially selected position, or any position on the axis of the reference pipeline. Since the reference pipeline has not suffered any corrosion and other damages and defects, when the third preset position is the reference When there are different positions on the axis line of the pipeline, the deviation between the obtained third magnetic field gradient modulus and the magnetic field gradient moduli is small and can be considered to be equal.

Optionally, in the above-mentioned technical scheme, in S5, the functional relationship between the fitting propagation factor and the measurement height, including:

G″表示 任一第三磁场梯度模量；S50. Calculate the propagation factor f corresponding to any third magnetic field gradient modulus according to the fourth formula until the propagation factor corresponding to each third magnetic field gradient modulus is obtained. The fourth formula is:

G" represents any third magnetic field gradient modulus;

H表示测量高度，第 五公式为

其中，A₁、A₂、B₁和B₂均为系数。S51. Determine according to the fifth formula: A ₁ =a ₁ , A ₂ =a ₂ , B ₁ =b ₁ , B ₂ =b ₂ , and the functional relationship between the propagation factor and the measurement height is obtained as:

H represents the measurement height, and the fifth formula is

Among them, A ₁ , A ₂ , B ₁ and B ₂ are all coefficients.

任一第三磁场梯度模量对应的传播 因子f，直至得到每个第三磁场梯度模量对应的传播因子，从而拟合f-H的 关系曲线，得到传播因子f与测试高度Hh的定量关系式即第五公式中的A₁、 A₂、B₁和B₂的具体值，由此得到A₁的具体值为a₁，A₂的具体值为a₂，B₁的 具体值为b₁，B₂的具体为b₂，即A₁＝a₁、A₂＝a₂、B₁＝b₁、B₂＝b₂，此时得到传播因子与测量高度之间的函数关系为：

在S20中，将h 带入函数关系，得到

According to the third magnetic field gradient modulus at different measurement heights at the third preset position on the axis line of the reference pipe, and according to the fourth formula:

The propagation factor f corresponding to any third magnetic field gradient modulus, until the propagation factor corresponding to each third magnetic field gradient modulus is obtained, so as to fit the relationship curve of fH, and obtain the quantitative relationship between the propagation factor f and the test height Hh, namely From the specific values of A ₁ , A ₂ , B ₁ and B ₂ in the fifth formula, the specific value of A ₁ is obtained as a ₁ , the specific value of A ₂ is a ₂ , and the specific value of B ₁ is b ₁ , Specifically, B ₂ is b ₂ , that is, A ₁ =a ₁ , A ₂ =a ₂ , B ₁ =b ₁ , and B ₂ =b ₂ . At this time, the functional relationship between the propagation factor and the measurement height is:

In S20, bringing h into the functional relationship, we get

In the above embodiments, although the steps are numbered S1, S2, etc., they are only specific embodiments given in this application. Those skilled in the art can adjust the execution order of S1, S2, etc. according to the actual situation. Within the protection scope of the present invention, it can be understood that in some embodiments, some or all of the above-mentioned embodiments may be included.

As shown in FIG. 4 , a pipeline corrosion monitoring system 200 according to an embodiment of the present invention includes a first acquisition module 210, a second acquisition module 220, a calculation module 230, and an early warning module 240;

The first acquisition module 210 is used for: acquiring the first preset position on the axis of the reference pipe, the first magnetic field gradient modulus when measuring the height in preset units;

The second acquisition module 220 is configured to: acquire the second preset position on the axis of the pipeline to be monitored, the second magnetic field gradient modulus at the preset measurement height, and obtain the second magnetic field gradient modulus according to the first magnetic field gradient modulus and the second magnetic field Gradient modulus, to determine the damage level index of the second preset position, wherein the specifications of the reference pipeline and the pipeline to be monitored are the same;

The calculation module 230 is used to: determine the current ratio between the current defect stress value of the second preset position and the yield strength corresponding to the material of the pipeline to be monitored according to the damage level index;

The pre-warning module 240 is used to: perform pre-warning according to the current ratio and the preset pre-warning strategy.

Obtaining and according to the first magnetic field gradient modulus corresponding to the reference pipeline, the second magnetic field gradient modulus can be automatically converted into the current defect stress value of the second preset position of the pipeline to be monitored and the yield corresponding to the material of the pipeline to be monitored in real time. The ratio between the strengths can effectively evaluate the stress safety state of the second preset position of the pipeline to be monitored. Moreover, it is the change of the magnetic signal of the corroded pipe section caused by the local stress change caused by the pipe wall defect of the pipeline to be monitored. Therefore, the impurities on the inner wall of the pipeline to be monitored will not cause the local stress change at the defect, so it will not affect the test accuracy. It greatly improves the accuracy and reliability of the test results.

Optionally, in the above technical solution, the first obtaining module 210 is specifically configured to:

Collect the initial magnetic field data when measuring the height in the preset unit with reference to the first preset position on the axis of the pipeline through the magnetic sensor;

y分量

和z分量

Obtained from the initial magnetic field data: the x-component of the magnetic field gradient perpendicular to the axis of the reference pipe

y-component

and the z component

According to the first formula, the first magnetic field gradient modulus G' is calculated,

Optionally, in the above technical solution, the second obtaining module 220 is specifically configured to:

其中，G_M＝Gf(h)，

A表示修正系数，G表示 第二磁场梯度模量，h表示预设测量高度。Use the second formula to calculate the damage level index F of the second preset position. The second formula is:

where G _M =Gf(h),

A represents the correction coefficient, G represents the second magnetic field gradient modulus, and h represents the preset measurement height.

Optionally, in the above technical solution, the computing module 230 is specifically used for:

The third formula is used to determine and calculate the current ratio. The third formula is σ _d /σ _s =(-283.1F ^1.08 +383.3), where σ _d represents the current defect stress value at the second preset position, and σ _s represents the pipeline to be monitored The corresponding yield strength of the material.

Optionally, in the above technical solution, a third acquisition module is also included;

The third acquisition module is used for: acquiring and fitting the functional relationship between the propagation factor and the measurement height according to the third magnetic field gradient moduli at different measurement heights at the third preset position on the axis of the reference pipeline.

Optionally, in the above technical solution, the third acquisition module is specifically used for:

G″表示任一第 三磁场梯度模量；Calculate the propagation factor f corresponding to any third magnetic field gradient modulus according to the fourth formula until the propagation factor corresponding to each third magnetic field gradient modulus is obtained. The fourth formula is:

G" represents any third magnetic field gradient modulus;

H表示测量高度，第五公式为

其中，A₁、A₂、B₁和B₂均为系数。Determined according to the fifth formula: A ₁ =a ₁ , A ₂ =a ₂ , B ₁ =b ₁ , B ₂ =b ₂ , the functional relationship between the propagation factor and the measurement height is obtained as:

H represents the measurement height, and the fifth formula is

Among them, A ₁ , A ₂ , B ₁ and B ₂ are all coefficients.

The above-mentioned parameters and steps of each unit module in the monitoring system 200 for monitoring pipeline corrosion of the present invention can refer to the parameters and steps in the embodiment of the monitoring method for pipeline corrosion. This will not be repeated.

This application has the following beneficial effects:

1) The equipment is easy to install and has good reliability. The remote monitoring method provided by the present invention does not need to excavate the pipeline, the monitoring system is directly installed on the surface position above the buried corrosion pipeline, and protective measures are taken. The equipment is not easy to be corroded, and it is convenient for regular inspection and maintenance, and has a long service life.

2) Accurately assess the safety status of the corroded pipe section. The remote monitoring method provided by the present invention can accurately obtain the stress change of the buried corroded pipe section through the remote magnetic field local stress calculation model of the corroded pipe section, thereby effectively evaluating the safety state of the pipeline.

3) There are few interference factors, and the data collection is stable. The remote monitoring method provided by the present invention is based on the magneto-mechanical effect, and the monitored magnetic signal change only comes from the local stress change at the defect, and is not affected by the accumulation of impurities on the inner wall of the pipeline, ensuring long-term effective monitoring of the safety state of the corroded pipe section.

The scope of application is: It is suitable for the safety monitoring of corrosion defects in pipelines in oil and gas stations.

The application prospects are as follows:

Pipelines are the key facilities for the transportation of national oil and gas resources, and defect detection and monitoring are important guarantees for the safe operation of pipelines. In-service oil and gas pipeline monitoring and high-precision quantification of defects are even more difficult worldwide, and there are many bottlenecks in key technologies and applications. The development of in-service oil and gas pipeline inspection and monitoring technology with independent intellectual property rights is of great significance and urgent need for breaking foreign technical barriers, ensuring national energy security, and seizing the commanding heights of international technology.

An electronic device according to an embodiment of the present invention includes a memory, a processor, and a program stored in the memory and running on the processor. When the processor executes the program, the steps of any one of the above-mentioned methods for monitoring pipeline corrosion are implemented.

Among them, the electronic equipment can be a computer, a mobile phone, etc. Correspondingly, its program is computer software or a mobile phone APP, etc., and the above-mentioned parameters and steps in an electronic equipment of the present invention can be referred to the above-mentioned pipeline corrosion The parameters and steps in the embodiments of the monitoring method are not repeated here.

As will be appreciated by one skilled in the art, the present invention may be embodied as a system, method or computer program product.

Therefore, the present disclosure can be embodied in the following forms, that is: it can be complete hardware, it can also be complete software (including firmware, resident software, microcode, etc.), or it can be a combination of hardware and software. Called a "circuit," "module," or "system." Furthermore, in some embodiments, the present invention may also be implemented in the form of a computer program product on one or more computer-readable media having computer-readable program code embodied thereon.

Any combination of one or more computer-readable media may be employed. The computer-readable medium may be a computer-readable signal medium or a computer-readable storage medium. A computer-readable storage medium can be, for example, but not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or a combination of any of the above. More specific examples (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 or Flash), fiber optics, portable compact disk read only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing. In this document, a 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.

Although the embodiments of the present invention have been shown and described above, it should be understood that the above-mentioned embodiments are exemplary and should not be construed as limiting the present invention. Embodiments are subject to variations, modifications, substitutions and variations.

Claims (10)

1. a monitoring method of pipeline corrosion, is characterized in that, comprises: acquiring the first preset position on the axis of the reference pipe, and the first magnetic field gradient modulus when measuring the height in preset units; Obtain a second preset position on the axis line of the pipeline to be monitored, the second magnetic field gradient modulus at the preset measurement height, and according to the first magnetic field gradient modulus and the second magnetic field gradient modulus, determining the damage level index of the second preset position, wherein the reference pipeline has the same specifications as the pipeline to be monitored; determining the current ratio between the current defect stress value at the second preset position and the yield strength corresponding to the material of the pipeline to be monitored according to the damage level index; Early warning is performed according to the current ratio and a preset early warning strategy. 2. The method for monitoring pipeline corrosion according to claim 1, wherein the process of obtaining the first magnetic field gradient modulus comprises: Collecting the first preset position on the axis of the reference pipeline by the magnetic sensor, the initial magnetic field data when measuring the height in preset units; Obtained from the initial magnetic field data: the x component of the magnetic field gradient perpendicular to the axis of the reference pipe

y-component

and the z component

According to the first formula, the first magnetic field gradient modulus G' is calculated,

3. The method for monitoring pipeline corrosion according to claim 2, wherein the process of determining the damage level index of the second preset position comprises: The damage level index F of the second preset position is calculated by using the second formula, and the second formula is:

where G _M =Gf(h),

A represents a correction coefficient, G represents the gradient modulus of the second magnetic field, and h represents the preset measurement height. 4. The method for monitoring pipeline corrosion according to claim 3, wherein the process of determining the current ratio comprises: The third formula is used to determine and calculate the current ratio, and the third formula is σ _d /σ _s =(-283.1F ^1.08 +383.3), where σ _d represents the current defect stress value at the second preset position, σ _s represents the yield strength corresponding to the material of the pipeline to be monitored. 5. A method for monitoring pipeline corrosion according to claim 4, characterized in that, further comprising: Obtaining and fitting the functional relationship between the propagation factor and the measurement height according to the third magnetic field gradient moduli at different measurement heights at the third preset position on the axis of the reference pipe. 6 . The method for monitoring pipeline corrosion according to claim 5 , wherein the fitting of the functional relationship between the propagation factor and the measurement height comprises: 6 . Calculate the propagation factor f corresponding to any third magnetic field gradient modulus according to the fourth formula until the propagation factor corresponding to each third magnetic field gradient modulus is obtained, and the fourth formula is:

G" represents any third magnetic field gradient modulus; Determined according to the fifth formula: A ₁ =a ₁ , A ₂ =a ₂ , B ₁ =b ₁ , B ₂ =b ₂ , the functional relationship between the propagation factor and the measurement height is obtained as:

H represents the measurement height, and the fifth formula is

Among them, A ₁ , A ₂ , B ₁ and B ₂ are all coefficients. 7. A remote monitoring system for corrosion defects in buried pipelines of oil and gas stations, characterized in that it comprises a first acquisition module, a second acquisition module, a calculation module and an early warning module; The first acquisition module is used for: acquiring the first preset position on the axis of the reference pipeline, and the first magnetic field gradient modulus when measuring the height in preset units; The second acquisition module is used for: acquiring the second preset position on the axis line of the pipeline to be monitored, the second magnetic field gradient modulus at the preset measurement height, and according to the first magnetic field gradient modulus and The second magnetic field gradient modulus determines the damage level index of the second preset position, wherein the reference pipeline has the same specifications as the pipeline to be monitored; The calculation module is configured to: determine the current ratio between the current defect stress value of the second preset position and the yield strength corresponding to the material of the pipeline to be monitored according to the damage level index; The early warning module is used for: performing early warning according to the current ratio and a preset early warning strategy. 8. The remote monitoring system for corrosion defects in buried pipelines of oil and gas stations according to claim 7, wherein the first acquisition module is specifically used for: Collect the first preset position on the axis line of the reference pipeline by the magnetic sensor, and the initial magnetic field data when measuring the height in preset units; Obtained from the initial magnetic field data: the x component of the magnetic field gradient perpendicular to the axis of the reference pipe

y-component

and the z component

According to the first formula, the first magnetic field gradient modulus G' is calculated,

9. The remote monitoring system for corrosion defects in buried pipelines of oil and gas stations according to claim 8, wherein the second acquisition module is specifically used for: The damage level index F of the second preset position is calculated by using the second formula, and the second formula is:

where G _M =Gf(h),

A represents a correction coefficient, G represents the second magnetic field gradient modulus, and h represents the preset measurement height. 10. An electronic device, comprising a memory, a processor and a program stored on the memory and running on the processor, wherein the processor implements the programs according to claims 1 to 6 when the processor executes the program The steps of any one of the methods for monitoring pipeline corrosion.

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