Remote detection system for oil gas leakage alarm

Abstract

The invention discloses a remote detection system for oil and gas leakage alarm, which relates to the technical field of oil and gas leakage alarm, and comprises a flow field stable core area acquisition module, an area filling degree acquisition module, a form distortion degree acquisition module and an abnormal partition judgment module. Comparing the real-time parameter with the reference parameter to obtain a filling deviation and a form deviation; whether leakage exists or not is judged by combining the two indexes of the regional filling degree and the form distortion degree, and misinformation caused by fluctuation of a single parameter is avoided; meanwhile, through partition detection, a leakage area can be accurately positioned, and clear guidance is provided for subsequent maintenance; the early-stage tiny leakage can be detected, the detection sensitivity is improved, meanwhile, the response speed of the early-stage leakage is remarkably improved, leakage is found in time, measures are taken, losses are reduced, safety accidents caused by oil and gas leakage are effectively avoided, safety risks are reduced, and safe and stable operation of oil and gas transmission is guaranteed.

Description

TECHNICAL FIELD

[0001] The application belongs to the technical field of oil and gas leakage alarm, and particularly relates to a remote detection system for oil and gas leakage alarm. BACKGROUND

[0002] In the process of oil and gas transportation, oil and gas pipe leakage is a serious problem, which not only causes resource waste and economic loss, but also may cause safety accidents and environmental pollution. However, the traditional oil and gas leakage detection method has many limitations, most of which mainly monitor the whole pipeline, and common methods include monitoring the pressure change of the whole pipeline, the overall flow difference or randomly selecting some areas for detection. These methods excessively rely on single indicators such as physical parameters such as pressure and concentration, and realize oil and gas leakage detection alarm based on the large physical quantity change caused after leakage. Only when the leakage amount reaches a certain degree, which is enough to cause significant changes in macroscopic physical parameters, can the detection system be triggered and an alarm signal be sent. For early small leakage, due to its small leakage amount, it is difficult to cause obvious changes in the overall physical parameters of the pipeline, so that the leakage problem cannot be effectively handled in the early stage. Further, it may gradually develop into a large-scale leakage accident, increasing the difficulty and cost of accident handling. When the leakage situation is more complex, such as special leakage point position and concealed leakage mode, false reporting may occur, and it is difficult to quickly and accurately locate the leakage point in the early stage of leakage, which delays the repair opportunity and further increases the harm of the leakage accident. Therefore, a remote detection system for oil and gas leakage alarm is proposed. SUMMARY

[0003] The purpose of the present application is to provide a remote detection system for oil and gas leakage alarm, which solves the technical problem of being difficult to quickly and accurately locate the leakage point in the early stage of leakage.

[0004] A remote detection system for oil and gas leakage alarm, comprising: A flow field stable core area acquisition module, which uniformly divides the oil and gas pipe to be detected into multiple regions, and obtains the respective flow field stable core areas in each region according to the inner wall diameter and the center point of the internal space of each region; A regional filling degree acquisition module, which makes the multiple experimental oil and gas pipes be in normal working conditions, forms a discrete point monitoring network on the pipe cross sections of different regions of each experimental oil and gas pipe, and acquires and analyzes the liquid level height data of different regions of each experimental oil and gas pipe multiple times according to the discrete point monitoring network to obtain the respective regional filling degrees of each region; A shape distortion degree acquisition module, which acquires the liquid level height data of different regions of each experimental oil and gas pipe multiple times according to the discrete point monitoring network, and calculates the respective shape distortion degrees of each region; The abnormal partition determination module obtains the real-time liquid level data of different regions of the oil and gas pipe to be detected by the discrete point monitoring network, inputs the data into the regional filling degree acquisition module and the shape distortion degree acquisition module respectively to obtain the real-time regional filling degree and the real-time shape distortion degree corresponding to different regions of the oil and gas pipe to be detected respectively, and analyzes the real-time regional filling degree and the real-time shape distortion degree corresponding to different regions and the regional filling degree and the shape distortion degree to determine the abnormal partition.

[0005] As a further scheme of the present application, the specific method for obtaining the flow field stable core area corresponding to each region is as follows: The inner wall diameter of each region of the oil and gas pipe is taken as the reference diameter Ri, the center point of the internal space of the part of the oil and gas pipe to be detected located in each detection region is taken as the center circle center Oi corresponding to each region, a spherical surface with a radius of ri=Ri / 2 is drawn in each region, and the spherical surface is taken as the flow field stable core area Hi corresponding to each region, wherein i represents different regions corresponding to the oil and gas pipe to be detected.

[0006] As a further scheme of the present application, the specific method for forming the discrete point monitoring network on the pipe cross section of each experimental oil and gas pipe is as follows: n1 liquid level sensors are uniformly arranged at an interval of 45° along the pipe circumference of different regions, and n2 liquid level sensors are arranged at the same interval distance in the axial direction, each liquid level sensor corresponds to a measuring point, a discrete point monitoring network of n1*n2 is formed, n1 and n2 are both positive integers and are greater than 4, and a1=n1*n2, a1 is the total number of measuring points on the monitoring network, the liquid level corresponding to each measuring point is obtained continuously for multiple times, and then the liquid level data of different regions of each experimental oil and gas pipe is obtained.

[0007] As a further scheme of the present application, the specific method for obtaining the regional filling degree corresponding to each region is as follows: A1: randomly select one from a plurality of regions as a target region; A2: randomly select one from a plurality of experimental oil and gas pipes as a target gas pipe; A3: mark the liquid level corresponding to each measuring point of the target region of the target gas pipe obtained continuously for multiple times as hje, hje is the liquid level of measuring point j in the e-th measurement, wherein j is a different measuring point, e is a different data acquisition time, e is a positive integer, e≥60, the pipe length L corresponding to the target region is obtained, the axial thickness Δz and the circumferential angle Δθ corresponding to each measuring point are calculated by Δz=L / n2 and Δθ=2π / n1, and the regional filling degree corresponding to each region is calculated by , the total volume Sj of the single sector column corresponding to each measuring point is calculated, r1 is the radius of the sphere corresponding to the stable core area of the target region flow field, the liquid level hje corresponding to each measuring point is marked, the liquid level hj1 of each measuring point is obtained, the ratio between the liquid level hj1 of each measuring point and the reference diameter R1 of the target region is obtained, and the sum of the product of each ratio and the total volume Sj of the single sector column corresponding to the measuring point is taken as the liquid surface volume V1 of the target region of the target gas pipe corresponding to this time, and the liquid surface volume of the remaining each time pipeline is calculated in the same way according to the liquid level corresponding to each measuring point, and then the liquid surface volume Ve of the target region of the target gas pipe corresponding to each time is obtained, and the mean value of the maximum and minimum of the liquid surface volume Ve is taken as the standard liquid surface volume E1 corresponding to the pipeline of the target region of the target gas pipe; A4: repeating steps A2-A3, i.e. obtaining the standard liquid surface volume Eb corresponding to the target region of a plurality of experimental oil and gas pipes, wherein b represents different experimental oil and gas pipes, analyzing the standard liquid surface volume Eb to obtain the regional filling degree Q1 corresponding to the target region; A5: repeating steps A2-A3, i.e. obtaining the regional filling degree Qi corresponding to each region, wherein i represents different regions of the oil and gas pipe.

[0008] As a further scheme of the application: the specific way to obtain the regional filling degree corresponding to the target region is: obtaining the absolute value of the difference between each liquid surface volume Eb and its mean value Ep, and the number c of values greater than a preset value Y1, when c is greater than a preset value Y2, the mean value of the maximum and minimum of each liquid surface volume Eb and the ratio between the volume of the stable core area of the target region flow field is taken as the regional filling degree Q1 corresponding to the target region, when c is less than or equal to the preset value Y2, the mean value of each liquid surface volume Eb and the volume of the stable core area of the target region flow field is taken as the regional filling degree Q1 corresponding to the target region, wherein the specific value of the preset value Y2 is greater than one half of the total number of experimental oil and gas pipes.

[0009] As a further scheme of the application: the specific way to obtain the regional filling degree corresponding to the target region is: A01: select the same target area as in step A1, the same target trachea as in step A2, the liquid level hj1 of each measuring point of the target trachea target area obtained from step A3, obtain the discrete value of the liquid level hj1, and take it as the liquid level change value K1 of the target area corresponding to this time of the target trachea, calculate the liquid volume in the pipeline of the remaining times in the same way according to the liquid level corresponding to each measuring point respectively, and then obtain the liquid level change value Ke corresponding to each time respectively of the target area of the target trachea, and obtain the mean value of the maximum and minimum of the liquid level change value Ke as the corresponding shape distortion degree M1 of the pipeline of the target area of the target trachea; A02: repeat step A01, that is, obtain the corresponding shape distortion degree Mi of each region.

[0010] As a further scheme of the application: the specific way of determining the abnormal partition is: Obtain the difference between the real-time area filling degree and the real-time shape distortion degree corresponding to each region of the oil and gas pipeline to be detected and the corresponding area filling degree and shape distortion degree, and mark them as filling deviation FAi and shape FBi corresponding to each region respectively, and take the sum of the product between the filling deviation FAi and the shape FBi corresponding to each region and the corresponding preset coefficients X1 and X2 as the liquid level deviation coefficient Gi corresponding to each region, the preset coefficients X1 and X2 satisfy 1=X1+X2, 0<X1<1 / 2<X2, mark the partition with a liquid level deviation coefficient Gi greater than a preset threshold Y3 as an abnormal partition and issue an alarm, otherwise, no processing is performed.

[0011] Compared with the prior art, the application has the following beneficial effects: (1) The application divides the pipeline to be detected into multiple regions according to length, defines a spherical region as the flow field stable core area in each region, pre-divides the pipeline partition, locks the most stable spherical region in each partition, reduces the detection range from the whole domain to the most sensitive region, and significantly improves the response speed of early leakage; (2) The application arranges a discrete point liquid level sensor network on the experimental pipeline to measure the liquid level, compares the liquid volume under normal working conditions with the volume of the flow field stable core area, calculates the area filling degree as a reference value, quantifies the abstract liquid surface concept into a specific volume, provides a data basis for subsequent leakage judgment, and calculates the volume through the liquid level of the discrete point monitoring network, which can accurately reflect the change of the core area oil and gas volume, and provides an important basis for subsequent judgment of whether the oil and gas pipeline leaks. (3) The present application reflects the irregularity of the liquid surface shape by extracting the discrete change value of the liquid level in each measurement, takes the mean value of the maximum and minimum value as the shape distortion degree, quantifies the stability of the liquid surface shape under normal working conditions, the larger the value of the shape distortion degree, the more irregular the oil and gas pipe liquid surface shape, early warning can be realized when the volume has not decreased significantly but the shape has been distorted, and the timeliness of detection is improved; (4) The present application, by real-time acquisition of the liquid level of each partition measuring point of the pipeline to be detected, compares the real-time parameters with the reference parameters, obtains the filling deviation and shape deviation, calculates the liquid level deviation coefficient through the preset weight coefficient, marks the partition as an abnormal partition when the coefficient exceeds the threshold value, combines the regional filling degree and shape distortion degree two indexes to judge whether there is leakage, avoids false alarm caused by single parameter fluctuation, at the same time, through partition detection, the leakage area can be accurately located, which provides clear guidance for subsequent maintenance, can detect early micro leakage, improve detection sensitivity, significantly improve the response speed of early leakage, find leakage in time and take measures, reduce loss, effectively avoid safety accidents caused by oil and gas leakage, reduce safety risk, and ensure the safe and stable operation of oil and gas transportation. BRIEF DESCRIPTION OF DRAWINGS

[0012] Fig. 1 The figure is a schematic diagram of the system framework structure of the present application; Fig. 2 The figure is a schematic diagram of the reference diameter of the target area and the structure of the flow field stable core area. DETAILED DESCRIPTION

[0013] The technical solutions of the present application will be described below in conjunction with the embodiments, obviously, the described embodiments are only part of the embodiments of the present application, not all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those skilled in the art without creative labor belong to the scope of protection of the present application.

[0014] Embodiment one: please refer to Figs. 1-2 The present application provides a kind of for oil and gas leakage alarm remote detection system, comprising; Flow field stable core area acquisition module, according to the specification type of the oil and gas pipe to be detected, obtains the corresponding three-dimensional profile of the oil and gas pipe to be detected, including its internal pipe wall diameter and the length of the pipe body corresponding to the oil and gas pipe to be detected, the oil and gas pipe to be detected is evenly divided into multiple areas along the length direction of pipe body, according to the inner wall diameter of the oil and gas pipe in each area and the center point of internal space, respectively draw a sphere in each area, and then obtain the corresponding flow field stable core area in each area, the specific way is: According to the type of the oil and gas pipeline to be detected, a three-dimensional profile pattern corresponding to the oil and gas pipeline to be detected is obtained, including the inner wall diameter of the oil and gas pipeline to be detected and the length of the pipe body corresponding to the oil and gas pipeline to be detected; The oil and gas pipeline to be detected is uniformly divided into multiple regions according to the length of the pipe body; The inner wall diameter of each region of the oil and gas pipeline is taken as a reference diameter Ri, the center point of the internal space of the part of the oil and gas pipeline to be detected located in each detection region is obtained, and is taken as the center circle center Oi corresponding to each region respectively, and a spherical surface with a radius of ri=Ri / 2 is drawn in each region according to the reference diameter Ri, and is taken as the flow field stable core region Hi corresponding to each region respectively; Where i represents different regions corresponding to the oil and gas pipeline to be detected, the spherical surface is defined as the flow field stable core region Hi under the normal working condition of the corresponding partition in each region, that is, when the liquid surface pattern in the spherical surface region is most stable under normal flow, the influence of flow velocity and disturbance is the smallest, which conforms to the common sense of fluid mechanics. The local pressure drop caused by pipeline leakage will cause the flow field to be disturbed, and the most stable region will be broken first. By focusing on this region, the detection sensitivity can be improved, false judgments can be reduced, and edge flow field fluctuation interference caused by non-leakage factors can be avoided. For example, for a pipeline with a diameter of 20 cm, the partition length is 10 m, and the diameter of the spherical surface can be set to 1 / 2 of the inner diameter of the pipeline, that is, 10 cm, and the volume corresponds to the liquid surface flow field stable core region of the partition under the minimum safe flow. This module divides the pipeline to be detected into multiple regions, and in each region, a spherical surface is defined as the flow field stable core region according to the inner diameter of the pipeline. The spherical surface is located at the center of the pipeline and is the most stable region of the fluid under normal working conditions and is least affected by external disturbances. When the oil and gas pipeline in each region leaks, the spherical surface of the corresponding region will be first invaded by the liquid surface depression, causing the liquid surface ratio to rapidly drop below the normal threshold, accompanied by morphological distortion. By pre-dividing the pipeline partition and locking the most stable spherical surface in each partition, the detection range is reduced from the whole domain to the most sensitive region, significantly improving the response speed of early leakage. When leakage occurs, the core region is affected first. By focusing on this most sensitive region, the system can detect leakage earlier and reduce false alarms caused by edge flow field fluctuations caused by non-leakage factors (such as turbulent flow at the edge of the pipeline).

[0015] The regional filling degree acquisition module is configured to set multiple oil and gas pipes with the same specification as the oil and gas pipe to be detected as experimental oil and gas pipes, so that the multiple experimental oil and gas pipes are all in a normal working condition, simultaneously arrange multiple liquid level sensors to form a discrete point monitoring network on the pipe cross sections in different regions of each experimental oil and gas pipe, and output the liquid surface height of each measuring point in the normal working condition through each liquid level sensor multiple times, calculate the liquid surface volume in the pipe in different regions, analyze the liquid surface volume in the pipe in different regions, and then obtain the corresponding regional filling degree in each region. The liquid surface volume refers to the volume of the region below the liquid surface in the space surrounded by the inner wall of the pipe. The specific manner is as follows: The specific manner of forming the discrete point monitoring network on the pipe cross sections in different regions of each experimental oil and gas pipe is as follows: The n1 liquid level sensors are arranged at an interval of 45° along the pipe circumference of different regions, and the n2 liquid level sensors are arranged at the same interval distance in the axial direction. Each liquid level sensor corresponds to a measuring point to form an n1*n2 discrete point monitoring network, and then form a discrete point monitoring network on the pipe cross sections in different regions of each experimental oil and gas pipe. The liquid level sensors output the liquid surface height of each measuring point in real time. n1 and n2 are both positive integers and are greater than 4. a1=n1*n2, and a1 is the total number of measuring points on the monitoring network. The specific manner of obtaining the corresponding regional filling degree in each region is as follows: Take the center of the starting cross section of each partition as the origin (0, 0, 0), the axial direction of the pipe as the z axis, the inner diameter direction of the cross section as the x axis, and the circumferential direction as the θ angle to form a cylindrical coordinate system (x, θ, z). Continuously obtain the corresponding liquid surface height of each measuring point, which is the sensor measurement value. According to the liquid surface height of each measuring point in each region obtained multiple times, calculate the liquid surface volume in the pipe in each region, analyze the liquid surface volume of each region, and obtain the corresponding regional filling degree in each region. The specific manner is as follows: A1: Randomly select one from multiple regions as a target region; A2: Randomly select one from multiple experimental oil and gas pipes as a target gas pipe; A3: Label the corresponding liquid surface height of each measuring point of the target region of the target gas pipe obtained continuously multiple times as hje. hje is the liquid surface height of measuring point j in the e-th measurement, where j is a different measuring point, and e is a different data acquisition time. e is a positive integer and e≥60. The liquid surface height refers to the vertical height of the liquid surface relative to the bottom of the pipe or the central axis. hje=0 corresponds to the bottom of the pipe, and hje=2r1 corresponds to the full pipe, where r1 is the radius of the spherical core region of the target region flow field. The length L of the pipeline corresponding to the target region is obtained, since n 2 measuring points are uniformly distributed along the axial direction, and n 1 measuring points are uniformly distributed along the circumferential direction, and then the axial thickness Δz and the circumferential angle Δθ corresponding to each measuring point are obtained by Δz = L / n 2 and Δθ = 2π / n 1 respectively; By , the total volume Sj of each measuring point is obtained respectively. First, the liquid level of each measuring point is calculated, and the liquid level of each measuring point is obtained from the liquid level of each measuring point, which is marked as hje, and the ratio between the liquid level hj1 of each measuring point and the reference diameter R1 of the target region is obtained, and the sum of the product of each ratio and the total volume Sj of the single sector cylinder corresponding to the measuring point is taken as the liquid surface volume V1 of the target region corresponding to the target gas pipe this time; That is, by , the liquid surface volume V1 of the target region corresponding to the target gas pipe this time is obtained, and R1 is the reference diameter of the target region, R1 = 2r1. In the same way, the liquid surface volume of the remaining times in the pipeline is calculated according to the liquid level of each measuring point, and then the liquid surface volume Ve of the target region of the target gas pipe is obtained, and the mean value of the maximum and minimum of the liquid surface volume Ve is taken as the standard liquid surface volume E1 corresponding to the pipeline of the target region of the target gas pipe; A4: repeat steps A2-A3, that is, the standard liquid surface volume Eb of the target region corresponding to the target gas pipe is obtained, wherein b represents different experimental oil and gas pipes; the absolute value of the difference between each liquid surface volume Eb and its mean value Ep is obtained, and the number c of the absolute value of the difference greater than the preset value Y1 is obtained, when c is greater than the preset value Y2, the mean value of the maximum and minimum of each liquid surface volume Eb is taken as the ratio between the volume of the target region flow field stable core area and the filling degree Q1 of the target region, when c is less than or equal to the preset value Y2, the ratio between the mean value of each liquid surface volume Eb and the volume of the target region flow field stable core area is taken as the filling degree Q1 of the target region, wherein the specific value of the preset value Y1 is determined by relevant personnel according to actual demand, the specific value of the preset value Y2 is greater than half of the total number of experimental oil and gas pipes, and the volume of the target region flow field stable core area is obtained by ; wherein r1 is the radius of the sphere corresponding to the target region flow field stable core area; A5: repeat steps A2-A3, that is, the filling degree Qi corresponding to each region is obtained, wherein i represents different regions of the oil and gas pipe; The discrete point liquid level sensor network is arranged on the experimental pipeline to measure the liquid level, through continuous multiple measurements, the discrete liquid level data is converted into liquid volume by using a mathematical model, finally, the liquid volume under normal working condition is compared with the volume of the stable core area of the flow field, the area filling degree is calculated as a reference value, the abstract liquid surface concept is quantified as a specific volume, which provides a data basis for subsequent leakage judgment, the liquid level of the discrete point monitoring network is calculated to accurately reflect the change of the core area oil and gas volume, which provides an important basis for subsequent judgment of whether the oil and gas pipeline leaks.

[0016] The shape distortion degree acquisition module calculates the shape distortion degree corresponding to each region according to the liquid level of each measuring point in each region obtained multiple times, and the specific mode is: A01: selecting the same target region as in step A1 and the same target gas pipe as in step A2, obtaining the liquid level hj1 of each measuring point in the target region of the target gas pipe in a single time from step A3, obtaining the discrete value of the liquid level hj1 as the liquid level change value K1 corresponding to the target region of the target gas pipe in this time, calculating the liquid volume in the remaining pipeline according to the liquid level corresponding to each measuring point in the same way, and then obtaining the liquid level change value Ke corresponding to each time in the target region of the target gas pipe, and obtaining the mean value of the maximum and minimum values of the liquid level change value Ke as the shape distortion degree M1 corresponding to the target region of the target gas pipe. A02: repeating step A01, so as to obtain the shape distortion degree Mi corresponding to each region; Based on the liquid level data of the experimental pipeline in the area filling degree acquisition module, the discrete change value of the liquid level in each measurement is extracted, the irregularity of the liquid surface shape is reflected, the mean value of the maximum and minimum values is taken as the shape distortion degree, the stability degree of the liquid surface shape under normal working condition is quantified as the reference threshold value of the liquid surface shape under normal working condition, the leakage will cause the liquid surface shape to be severely distorted, the greater the value of the shape distortion degree, the more irregular the liquid surface shape of the oil and gas pipeline, the liquid surface fluctuates violently when leaking, the shape distortion degree increases significantly, which is usually an early signal of leakage, and the early warning can be realized when the volume has not decreased significantly but the shape has been distorted, improving the timeliness of detection.

[0017] The abnormal partition determination module obtains the real-time liquid level at each measuring point of each different region of the oil and gas pipeline to be detected in real time, and inputs the real-time liquid level into the regional filling degree acquisition module and the shape distortion degree acquisition module, respectively, to obtain the real-time regional filling degree and the real-time shape distortion degree corresponding to each different region of the oil and gas pipeline to be detected, respectively, and the difference between the real-time regional filling degree and the real-time shape distortion degree corresponding to each different region of the oil and gas pipeline to be detected and the regional filling degree and the shape distortion degree corresponding thereto, and marks the difference as the filling deviation FAi and the shape deviation FBi corresponding to each different region, respectively, and takes the sum of the product between the filling deviation FAi and the shape deviation FBi corresponding to each different region and the preset coefficients X1 and X2 corresponding thereto as the liquid level deviation coefficient Gi corresponding to each different region, respectively, wherein the preset coefficients X1 and X2 satisfy 1 = X1 + X2, 0 < X1 < 1 / 2 < X2; the partition with the liquid level deviation coefficient Gi greater than a preset threshold Y3 is marked as an abnormal partition and an alarm is issued, otherwise, no processing is performed, and the specific value of the preset threshold Y3 is determined by an actual worker according to actual needs; The volume filling degree, i.e., the change in the liquid level, and the shape distortion degree, i.e., the irregularity of the liquid level shape, are combined, and the weight coefficient X1 < X2 is used to highlight the sensitivity of the shape distortion, i.e., the shape change often occurs earlier than the significant decrease in the volume when leakage occurs. The liquid level height of each partition measuring point of the pipeline to be detected is collected in real time, and the real-time parameters are calculated by inputting the regional filling degree and the shape distortion degree module; the filling deviation and the shape deviation are obtained by comparing the real-time parameters with the reference parameters; the liquid level deviation coefficient is calculated by the preset weight coefficient, and the partition is marked as an abnormal partition when the coefficient exceeds the threshold value; the existence of leakage is determined by combining the two indexes of the regional filling degree and the shape distortion degree; the abnormal characteristics of the quantity and the shape are comprehensively considered by the double-dimensional deviation weighted fusion, and the false alarm caused by the fluctuation of a single parameter is avoided; at the same time, the leakage region can be accurately positioned by partition detection, and clear guidance is provided for subsequent maintenance; The scheme reduces the detection range from the whole region to the most sensitive region by pre-dividing the pipeline partitions and locking the most stable spherical region in each partition, and the core region is affected first when leakage occurs, which can detect the leakage earlier and improve the response speed of early leakage; the stable core region of the flow field is focused, and the existence of leakage is determined by multi-dimensional fusion judgment combining the two indexes of the regional filling degree and the shape distortion degree, which can accurately and reliably detect the oil and gas leakage, reduce the false judgment and the missed judgment, detect the early and small leakage, improve the detection sensitivity, significantly improve the response speed of early leakage, discover the leakage in time and take measures, reduce the loss, effectively avoid the safety accidents caused by oil and gas leakage, reduce the safety risk, and ensure the safe and stable operation of oil and gas transportation.

[0018] The above formulas are all dimensionless values calculated, the formulas are obtained by collecting a large amount of data to simulate a formula of the most recent real situation, and preset parameters and threshold values in the formulas are set by a person skilled in the art according to actual conditions.

[0019] The above merely provides a specific implementation of the present application, but the protection scope of the present application is not limited thereto, any person skilled in the art can easily think of changes or replacements within the technical range disclosed by the present application, which should be covered in the protection scope of the present application. Therefore, the protection scope of the present application should be subject to the protection scope of the claims.

Claims

1. A remote detection system for oil and gas leakage alarm, characterized in that: include: The flow field stable core area acquisition module evenly divides the oil and gas pipe to be inspected into multiple areas, and obtains the flow field stable core area corresponding to each area based on the inner wall diameter and the center point of the internal space of each area; The regional filling degree acquisition module ensures that multiple experimental oil and gas pipelines are under normal operating conditions. At the same time, a discrete point monitoring network is formed on the pipeline cross-section of different areas of each experimental oil and gas pipeline. Based on the discrete point monitoring network, the liquid level height data of different areas of each experimental oil and gas pipeline are repeatedly acquired and analyzed to obtain the regional filling degree corresponding to each area. The morphological distortion acquisition module calculates the morphological distortion corresponding to each area based on the liquid level height data of different areas of each experimental oil and gas pipeline repeatedly collected by the discrete point monitoring network; The abnormal partition judgment module obtains the real-time liquid level height data of different areas of the oil and gas pipeline to be inspected based on the discrete point monitoring network, and inputs them into the regional fullness acquisition module and the morphological distortion acquisition module respectively to obtain the real-time regional fullness and real-time morphological distortion corresponding to different areas of the oil and gas pipeline to be inspected. The real-time regional fullness and real-time morphological distortion corresponding to different areas, as well as the regional fullness and morphological distortion, are analyzed to judge the abnormal partition interval.

2. A remote detection system for oil and gas leakage alarm according to claim 1, characterized in that: The specific method of obtaining the corresponding stable core area of ​​the flow field in each area is as follows: The inner wall diameter of the oil and gas pipe in each area is taken as the reference diameter Ri, and the center point of the internal space of the part of the oil and gas pipe to be detected located in each detection area is taken as the center circle center Oi corresponding to each area. A sphere with a radius of ri=Ri / 2 is drawn in each area and used as the flow field stability core area Hi corresponding to each area, where i refers to the different areas corresponding to the oil and gas pipe to be detected.

3. A remote detection system for oil and gas leakage alarm according to claim 2, characterized in that: The specific method of forming a discrete point monitoring network on the pipeline cross section in different areas of each experimental oil and gas pipeline is as follows: n1 liquid level sensors are evenly arranged at 45° intervals along the circumference of the pipeline in different areas, and n2 liquid level sensors are arranged at the same intervals in the axial direction. Each liquid level sensor corresponds to a measuring point, forming an n1×n2 discrete point monitoring network. Both n1 and n2 are positive integers and both are greater than 4, and a1=n1×n2, a1 is the total number of measuring points on the monitoring network. The liquid level height corresponding to each measuring point is obtained repeatedly, and then the liquid level height data of different areas of each experimental oil and gas pipeline are obtained.

4. A remote detection system for oil and gas leakage alarm according to claim 3, characterized in that: The specific method of obtaining the regional fullness corresponding to each area is: A1: Randomly select one of the multiple regions as the target region; A2: Randomly select one of the experimental oil and gas pipes as the target pipe; A3: Mark the liquid level heights corresponding to the various measurement points obtained in the target area of ​​the target trachea for multiple times as hje, where hje is the liquid level height at the measurement point j in the e-th measurement, where j is a different measurement point and e is a different number of data acquisitions. e is a positive integer, e≥60. Obtain the pipe length L corresponding to the target area. Calculate the axial thickness Δz and circumferential angle Δθ corresponding to each measurement point using: Δz=L / n2 and Δθ=2π / n1. , calculate and obtain the total volume Sj of a single sector-shaped cylinder corresponding to each measuring point, r1 is the radius of the sphere corresponding to the stable core area of ​​the flow field in the target area, obtain the single liquid level height hj1 of each measuring point from the liquid level height corresponding to each measuring point marked as hje, obtain the ratio between the liquid level height hj1 of each measuring point and the reference diameter R1 of the target area, and take the sum of the products of each ratio and the total volume Sj of a single sector-shaped cylinder of the corresponding measuring point as the liquid level volume V1 in the pipeline corresponding to the target area of ​​the target trachea. Use the same method to calculate the liquid level volumes in the remaining pipelines according to the liquid level heights corresponding to each measuring point, and then obtain the liquid level volumes Ve in the pipeline corresponding to each time in the target area of ​​the target trachea, and obtain the average of the maximum and minimum values ​​of the liquid level volume Ve as the standard liquid level volume E1 corresponding to the pipeline of the target area of ​​the target trachea; A4: Repeat steps A2-A3 to obtain the standard liquid surface volumes Eb corresponding to the target area for multiple experimental oil and gas pipes, where b refers to different experimental oil and gas pipes. Analyze the standard liquid surface volumes Eb to obtain the regional filling degree Q1 corresponding to the target area. A5: Repeat steps A2-A3 to obtain the regional fullness Qi corresponding to each area, where i represents different areas of the oil and gas pipeline.

5. A remote detection system for oil and gas leakage alarm according to claim 4, characterized in that: The specific method of obtaining the regional fullness corresponding to the target area is: Obtain the number c of the absolute values ​​of the differences between each liquid surface volume Eb and its mean Ep that are greater than the preset value Y1. When c is greater than the preset value Y2, the ratio of the mean of the maximum and minimum values ​​of each liquid surface volume Eb to the volume of the stable core area of ​​the flow field in the target area is used as the regional fullness Q1 corresponding to the target area. When c is less than or equal to the preset value Y2, the ratio of the mean of each liquid surface volume Eb to the volume of the stable core area of ​​the flow field in the target area is used as the regional fullness Q1 corresponding to the target area. The specific value of the preset value Y2 is greater than half of the total number of experimental oil and gas pipes.

6. A remote detection system for oil and gas leakage alarm according to claim 5, characterized in that: The specific method of obtaining the corresponding morphological distortion degree in each area is as follows: A01: Select the same target area as in step A1 and the same target trachea as in step A2, obtain the single liquid level height hj1 at each measuring point in the target area of ​​the target trachea from step A3, obtain the discrete value of the liquid level height hj1, and use it as the liquid level height change value K1 corresponding to the target area of ​​the target trachea at that time. Use the same method to calculate the liquid level volume in the remaining pipes based on the liquid level height corresponding to each measuring point, and then obtain the liquid level height change value Ke corresponding to each time in the target area of ​​the target trachea. Obtain the average of the maximum and minimum values ​​of the liquid level height change values ​​Ke as the morphological distortion degree M1 corresponding to the target area of ​​the target trachea; A02: Repeat step A01 to obtain the morphological distortion degree Mi corresponding to each area.

7. A remote detection system for oil and gas leakage alarm according to claim 6, characterized in that: The specific method for determining abnormal intervals is as follows: Obtain the differences between the real-time regional filling degree and real-time morphological distortion degree corresponding to different areas of the oil and gas pipe to be inspected and the corresponding regional filling degree and morphological distortion degree, and mark them as the filling deviation FAi and morphology FBi corresponding to different areas respectively. According to the filling deviation FAi and morphology FBi, obtain the liquid level deviation coefficient Gi corresponding to different areas respectively. Mark the partition whose liquid level deviation coefficient Gi is greater than the preset threshold value Y3 as an abnormal partition and issue an alarm. Otherwise, no processing is performed.

8. The remote detection system for oil and gas leakage alarm according to claim 7, characterized in that: The specific method of obtaining the liquid level deviation coefficient corresponding to different areas is: The sum of the products of the filling deviations FAi and morphology FBi corresponding to different areas and their corresponding preset coefficients X1 and X2 is taken as the liquid level deviation coefficient Gi corresponding to different areas. The preset coefficients X1 and X2 satisfy 1=X1+X2, 0<X1<1 / 2<X2.

9. The remote detection system for oil and gas leakage alarm according to claim 5, characterized in that: The specific method of obtaining the volume of the stable core area of ​​the flow field in the target area is: pass , calculate the volume of the stable core area of ​​the flow field in the target area .

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