Gas leak detection system based on distributed sensor technology

Abstract

The present invention discloses a gas leak detection system based on distributed sensor technology, which relates to the technical field of gas leak detection and solves the technical problem in the prior art that the optical fiber vibration sensor technology cannot be combined with pipeline analysis, thereby reducing the accuracy of gas leak detection. Specifically, the system comprises a pipeline position detection and identification unit, which detects and identifies the pipeline covered by the distributed sensor, and determines whether the gas transmission pipeline has the conditions for leakage during operation based on the detection and identification. If the conditions are met, position detection is performed to evaluate the leakage risk; a sensor detection and control unit, which detects the optical fiber vibration sensor and reasonably sets the position; after the position setting is completed, a data processing and identification unit processes and identifies the collected data of the optical fiber vibration sensor.

Description

Technical Field

[0001] The present invention relates to the technical field of gas leakage detection, and in particular to a gas leakage detection system based on distributed sensor technology. Background Art

[0002] Distributed fiber-optic vibration sensors are based on the photoelastic effect and Rayleigh scattering of optical fibers. When an optical fiber is subjected to external vibrations, its refractive index and length undergo minute changes, resulting in changes in the phase and polarization state of light traveling through the fiber. By measuring and analyzing these changes, vibration information along the fiber can be detected, and parameters such as the vibration's location, frequency, and amplitude can be determined.

[0003] Existing gas leak detection adopts fixed gas leak detection in point-like, dispersed, and local areas. It cannot locate the leakage point in pipelines that are long and highly concealed. It is not sensitive enough to detect trace leaks in pipeline welds, valves, flanges and other parts, and gas pipeline leaks in open areas. There are many limitations and blind spots for hidden dangers. It is also impossible to combine pipeline analysis with fiber optic vibration sensor technology, which reduces the accuracy of gas leak detection.

[0004] In view of the above technical defects, a solution is now proposed. Summary of the Invention

[0005] The purpose of the present invention is to solve the above-mentioned problems and to propose a gas leakage detection system based on distributed sensor technology.

[0006] The purpose of the present invention can be achieved through the following technical solutions:

[0007] A gas leak detection system based on distributed sensor technology includes a gas leak detection platform, wherein the gas leak detection platform is communicatively connected to a pipeline position detection and identification unit, a sensor detection and control unit, and a data processing and identification unit;

[0008] The pipeline position detection and identification unit detects and identifies the pipelines covered by the distributed sensors. Based on the detection and identification, it determines whether the gas pipeline has the conditions for leakage during operation. If the conditions are met, it performs position detection and assesses the leakage risk.

[0009] Sensor detection and control unit, which detects the optical fiber vibration sensor and reasonably sets its position;

[0010] After the position setting is completed, the data processing and identification unit processes and identifies the collected data of the optical fiber vibration sensor.

[0011] As a preferred embodiment of the present invention, the process of the pipeline position detection and identification unit is as follows:

[0012] According to the splicing process of the gas transmission pipeline and the surface texture of the pipeline, the gas transmission pipeline is divided into the overall position and the split position;

[0013] The overall and split locations are tested for leak conditions, where the leak condition is the energy difference between the inside and outside of the gas pipeline when the gas is being transported. Physical barriers are also set at the gas pipeline locations.

[0014] When the entire gas transmission pipeline is used as the detection subject, the internal pressure average value during the gas transportation period and the non-operation period in the gas transmission pipeline is obtained. If the internal pressure average value is within the set pressure average range, it is judged that the risk of pressure deviation in the gas transmission of the current gas transmission pipeline is low. Otherwise, it is inferred that the pressure deviation risk is high. The gas leakage detection platform controls the gas transmission of the gas transmission pipeline to adjust the transmission volume or transmission speed.

[0015] As a preferred embodiment of the present invention, when the internal pressure mean is within the set range, the peak value of the internal pressure mean is used as the comparison pressure value, and combined with the ambient pressure value of the area where the gas transmission pipeline is located at the moment corresponding to the comparison pressure value, the comparison pressure value and the ambient pressure value are continuously compared starting from this moment. During the comparison: when the comparison pressure value is higher than the ambient pressure value, the corresponding moment is marked as an internal strong moment; conversely, when the comparison pressure value is lower than the ambient pressure value, the corresponding moment is marked as an external strong moment.

[0016] As a preferred embodiment of the present invention, according to the statistics of adjacent comparison moments, if the pressure difference corresponding to the internal strong moment or the external strong moment in the continuous detection period exceeds the pressure difference threshold, or the maximum value of the continuous alternation frequency of the internal strong moment and the external strong moment as adjacent moments exceeds the alternation frequency threshold, then it is inferred that the gas transmission pipeline operation stage during the continuous detection period has the conditions for leakage; conversely, if the pressure difference corresponding to the internal strong moment or the external strong moment in the continuous detection period does not exceed the pressure difference threshold, and the maximum value of the continuous alternation frequency of the internal strong moment and the external strong moment as adjacent moments does not exceed the alternation frequency threshold, then it is inferred that the gas transmission pipeline operation stage during the continuous detection period does not have the conditions for leakage.

[0017] As a preferred embodiment of the present invention, after the conditions for leakage are met, the overall position and the split position are detected;

[0018] During the operating period when the conditions for leakage occur, the performance parameters of the physical isolators corresponding to the overall position and the split position of the same type of physical isolators are collected; the floating trend of the performance parameters is obtained based on the specific values ​​of the performance parameters of the physical isolators at each moment. When the floating trend of the performance parameters shows a downward trend, a leakage risk signal is generated and sent to the gas leakage detection platform. When the floating trend of the performance parameters does not show a downward trend, a leakage safety signal is generated and sent to the gas leakage detection platform.

[0019] As a preferred embodiment of the present invention, when there is a risk of leakage, if there is a deviation in the downward trend of the performance parameters corresponding to the overall position and the split position, and the downward trend of the overall position is slower than the downward trend of the split position, a warning protection signal is generated and sent to the gas leakage detection platform; if there is no deviation in the downward trend of the performance parameters corresponding to the overall position and the split position, or the downward trend of the overall position is not slower than the downward trend of the split position, a synchronous warning protection signal is generated and sent to the gas leakage detection platform.

[0020] As a preferred embodiment of the present invention, the process of the sensor detecting the control unit is as follows:

[0021] The overall and split positions are analyzed, and the current environment is simulated using an optical fiber vibration sensor. The fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span corresponding to the optical fiber vibration sensor when internal pipeline deformation occurs are collected.

[0022] If the fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span corresponding to the fiber optic vibration sensor when internal pipeline deformation occurs are both within the corresponding span threshold range, it is inferred that the current simulation operation position is suitable for setting up the sensor;

[0023] If the fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span of the fiber optic vibration sensor corresponding to the internal pipeline deformation are not both within the corresponding span threshold ranges, it is inferred that the current simulation operation location is not suitable for sensor installation.

[0024] As a preferred embodiment of the present invention, locations with leakage conditions are marked as leakage risk locations, and the distribution density of the leakage risk locations corresponding to the gas transmission pipeline is calculated;

[0025] If the distribution density is higher than the set density threshold, the installation method is: set up a sensor core processor and place it at the center of the location, and install the sensors centrally with the center as the origin. The processor sends the collected data of the sensors in a centralized manner; if the distribution density is lower than the set density threshold, the installation method is: use a single sensor as the main body and cover the corresponding location, and send the real-time collected data in a distributed manner.

[0026] As a preferred embodiment of the present invention, the process of the data processing and identification unit is as follows:

[0027] Fiber optic vibration sensors are used to detect various positions in the gas delivery pipeline, and phase change analysis and polarization state change analysis are performed through the collected data. During the operation of the gas delivery pipeline, the phase of light transmitted in the optical fiber when external vibration occurs is collected, and at the same time, the light at various positions in the current gas delivery pipeline is collected as changes in the distribution state of electromagnetic waves.

[0028] As a preferred embodiment of the present invention, if the phase of light transmitted in the optical fiber fluctuates during external vibration, or the distribution state of light as an electromagnetic wave at various positions in the current gas delivery pipeline changes, it is inferred that a gas leak occurs at the current position, and the current position is sent to the gas leak detection platform; if the phase of light transmitted in the optical fiber does not fluctuate during external vibration, and the distribution state of light as an electromagnetic wave at various positions in the current gas delivery pipeline does not change, it is inferred that no gas leak occurs at the current position, and continuous monitoring is performed.

[0029] Compared with the prior art, the present invention has the following beneficial effects:

[0030] 1. In the present invention, the pipelines monitored by distributed sensors are detected and identified, and the risk of gas leakage points is estimated through pipeline detection and identification. At the same time, the risk estimation can be used as an effective basis for targeted setting of sensor control to ensure that the distributed sensor point fits more effectively with the current pipeline gas transportation. At the same time, pipeline position detection can also provide timely warnings, reduce the risk of gas leakage in the pipeline, and improve the efficiency and feasibility of gas transportation.

[0031] 2. In the present invention, the optical fiber vibration sensor is detected and its position is reasonably set to facilitate the detection of the gas transmission pipeline, and synchronous processing is performed based on the detection data processing combined with the various types of early warning signals received; if a synchronous early warning protection signal is received, synchronous monitoring and early warning control are performed on various types of positions, and if a warning protection signal is received, targeted monitoring and early warning are performed on the split positions; if a leakage risk signal is received, the sensor is used to detect and repair the leakage;

[0032] The collected data of the optical fiber vibration sensor is processed and identified, and the current degree of gas leakage is inferred through data processing. The leakage position is located in real time according to the change of the leakage degree, so as to improve the real-time accurate control based on the leakage position during the leak repair and avoid leakage deviation during the leakage reduction process, which will cause a decrease in repair efficiency. BRIEF DESCRIPTION OF THE DRAWINGS

[0033] To facilitate understanding by those skilled in the art, the present invention is further described below with reference to the accompanying drawings.

[0034] Figure 1 It is a system principle block diagram of the present invention as a whole;

[0035] Figure 2 This is a flow chart of the method of the pipeline position detection and identification unit in the present invention. DETAILED DESCRIPTION

[0036] In order to enable those skilled in the art to better understand the solutions of the present invention, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. All other embodiments obtained by ordinary technicians in this field based on the embodiments of the present invention without making any creative efforts shall fall within the scope of protection of the present invention.

[0037] References herein to "embodiments" mean that a particular feature, structure, or characteristic described in connection with the embodiments may be included in at least one embodiment of the present invention. The appearance of this phrase in various places in the specification does not necessarily refer to the same embodiment, nor does it constitute a separate or alternative embodiment that is mutually exclusive of other embodiments. It is understood, both explicitly and implicitly, by those skilled in the art that the embodiments described herein may be combined with other embodiments.

[0038] See also Figure 1 As shown, a gas leak detection system based on distributed sensor technology includes a gas leak detection platform, wherein the gas leak detection platform is communicatively connected to a pipeline position detection and identification unit, a sensor detection and control unit, and a data processing and identification unit. It should be explained that the threshold values ​​involved in this application are parameters set by those skilled in the art in actual operation based on historical operation processes and human experience, and are used for real-time parameter detection.

[0039] The gas leakage detection platform generates a pipeline position detection identification signal and sends the pipeline position detection identification signal to the pipeline position detection identification unit;

[0040] The pipeline position detection and identification unit is used to receive the pipeline position detection and identification signal, and after receiving it, detect and identify the pipeline covered by the distributed sensor. Through pipeline detection and identification, the risk of gas leakage points is estimated. At the same time, the risk estimation can be used as an effective basis for targeted setting of sensor control to ensure that the distributed sensor point fits more effectively with the current pipeline gas transportation. At the same time, pipeline position detection can also provide timely warnings, reduce the risk of gas leakage in the pipeline, and improve the efficiency and feasibility of gas transportation;

[0041] See also Figure 2 As shown in the figure, the gas transmission pipeline is divided into positions according to the splicing process and the surface texture of the pipeline, that is, the gas transmission pipeline is divided into an integral position and a split position. The integral position indicates that the surface of the gas transmission pipeline is made of an integral material without cutting or welding; the split position indicates that the surface of the gas transmission pipeline is not made of an integral material and there are cutting, splicing or welding.

[0042] The overall and split locations are tested for leak conditions. The leak conditions are defined as energy differences between the inside and outside of the gas pipeline during gas transportation, specifically temperature, pressure, and velocity differences. Physical barriers, such as thermal insulation layers, are also placed at the gas pipeline locations.

[0043] When the entire gas transmission pipeline is used as the detection subject, the internal pressure average value of the gas transmission pipeline during the gas transportation period and the non-operation period is obtained. If the internal pressure average value is within the set pressure average value range, it is judged that the risk of pressure deviation in the current gas transmission pipeline is low. Otherwise, it is inferred that the pressure deviation risk is high. The gas leakage detection platform controls the gas transmission of the gas transmission pipeline to adjust the transmission volume or transmission speed.

[0044] Then, when the internal pressure average is within the set range, the peak value of the internal pressure average is used as the comparison pressure value, and combined with the ambient pressure value of the gas transmission pipeline area at the time corresponding to the comparison pressure value, the comparison pressure value and the ambient pressure value are continuously compared starting from this time. When the comparison pressure value is higher than the ambient pressure value, the corresponding moment is marked as the internal strong moment; conversely, when the comparison pressure value is lower than the ambient pressure value, the corresponding moment is marked as the external strong moment;

[0045] According to the statistics of adjacent comparison moments, if the pressure difference corresponding to the internal strong moment or the external strong moment during the continuous detection period exceeds the pressure difference threshold, or the maximum value of the continuous alternation frequency of the internal strong moment and the external strong moment as adjacent moments exceeds the alternation frequency threshold, then it is inferred that the gas transmission pipeline operation stage during the continuous detection period has the conditions for leakage; conversely, if the pressure difference corresponding to the internal strong moment or the external strong moment during the continuous detection period does not exceed the pressure difference threshold, and the maximum value of the continuous alternation frequency of the internal strong moment and the external strong moment as adjacent moments does not exceed the alternation frequency threshold, then it is inferred that the gas transmission pipeline operation stage during the continuous detection period does not have the conditions for leakage;

[0046] Once the conditions for leakage are met, test the overall position and the split position;

[0047] During the operating period when conditions for leakage occur, the performance parameters of the physical isolators corresponding to the overall position and the split position of the same type of physical isolators are collected, such as the internal temperature fluctuation reduction value and other parameters for the thermal insulation layer; the floating trend of the performance parameters is obtained based on the specific values ​​of the performance parameters of the physical isolators at each moment. When the floating trend of the performance parameters shows a downward trend, it is inferred that the probability of leakage corresponding to the overall position and the split position is high, a leakage risk signal is generated and sent to the gas leakage detection platform; when the floating trend of the performance parameters does not show a downward trend, it is inferred that the probability of leakage corresponding to the overall position and the split position is low, a leakage safety signal is generated and sent to the gas leakage detection platform;

[0048] In the event of leakage risk, if there is a deviation in the downward trend of the corresponding performance parameters of the overall position and the split position, and the downward trend of the overall position is slower than that of the split position, it is inferred that the leakage level of the split position is higher than that of the overall position, and a warning protection signal is generated and sent to the gas leakage detection platform;

[0049] If there is no deviation in the downward trend of the corresponding performance parameters of the overall position and the split position, or the downward trend of the overall position is not slower than the downward trend of the split position, it is inferred that the deviation between the leakage degree of the split position and the leakage degree of the overall position is within the set range, and a synchronous early warning protection signal is generated and sent to the gas leakage detection platform;

[0050] After receiving various types of warning signals, the gas leakage detection platform generates a sensor detection control signal and sends it to the sensor detection control unit. The optical fiber vibration sensor is detected and its position is reasonably set to facilitate the detection of the gas transmission pipeline. The detection data is processed in combination with the various types of received warning signals for synchronous processing. For example, if a synchronous warning protection signal is received, various types of positions are synchronously monitored and warned. For a warning protection signal, a split position is targeted for monitoring and warning. Leak risk signals are used in conjunction with sensors to detect and repair leaks.

[0051] The sensor detection and control unit is used to detect and analyze the environment around the gas transmission pipeline after receiving the sensor detection and control signal to infer whether the surrounding environment is suitable for installing the optical fiber vibration sensor for detection, improve the detection accuracy of the optical fiber vibration sensor, ensure that real-time monitoring can meet the needs of the current location, and ensure that data at each location is not lost, so as to improve the accuracy of gas transmission pipeline leakage detection;

[0052] The overall and split positions are analyzed, and the current environment is simulated using a fiber optic vibration sensor. The fiber optic refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber optic transmission loss span corresponding to the fiber optic vibration sensor when internal pipeline deformation occurs are collected. The fiber optic transmission loss span can be used to monitor the transmission of the optical fiber in a fixed area. If the test accuracy deviates within the same fiber optic test duration, it indicates that the transmission loss has increased. The simulation operation is expressed by combining the current environmental parameters and the influencing parameters of pipeline transportation with the sensor's own performance parameters to infer whether the actual detection efficiency can be achieved.

[0053] If the fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span corresponding to the fiber optic vibration sensor when internal pipeline deformation occurs are both within the corresponding span threshold range, it is inferred that the current simulation operation position is suitable for setting up the sensor;

[0054] If the fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span of the fiber optic vibration sensor corresponding to the internal deformation of the pipeline are not both within the corresponding span threshold range, it is inferred that the current simulation operation location is not suitable for setting up the sensor;

[0055] After obtaining the locations suitable for setting up sensors, the locations with leakage conditions are marked as leakage risk locations, and the distribution density of the leakage risk locations corresponding to the gas transmission pipeline is calculated, where the distribution density is expressed as the proportion of the number of leakage risk locations in the current area;

[0056] The distribution density of leakage risk locations suitable for sensor installation is analyzed. If the distribution density is higher than the set density threshold, the sensor is installed at the current suitable sensor location. The installation method is: set up a sensor core processor and place it at the center of the location. The sensors are centrally installed with the center as the origin. The processor sends the collected data of the sensors in a centralized manner. It should be explained that if the density is too high, the floating buffer time of each location is short and the floating deviation of the pipeline transmission parameters is small. Therefore, synchronous transmission can better reflect the current leakage situation in real time.

[0057] If the distribution density is lower than the set density threshold, the sensor is installed at the currently suitable sensor location. The installation method is: use a single sensor as the main body and cover the corresponding location. The real-time collected data is distributed and sent to avoid inconsistent update cycles of the data collected by the sensors. Synchronous sending will make the data at each location inconsistent and the leakage status cannot be obtained in a timely and effective manner.

[0058] After completing the sensor detection and setting the position, the gas leak detection platform generates a data processing identification signal and sends the data processing identification signal to the data processing identification unit;

[0059] After receiving the data processing and identification signal, the data processing and identification unit processes and identifies the data collected by the optical fiber vibration sensor, infers the current degree of gas leakage through data processing, and locates the leakage position in real time according to the change of the leakage degree, so as to improve the ability to accurately control the leakage position in real time during the leakage repair, and avoid leakage deviation during the leakage reduction process, which will cause a decrease in repair efficiency;

[0060] Fiber optic vibration sensors are used to detect various locations in the gas pipeline, and phase and polarization state change analysis is performed on the collected data.

[0061] During the operation of the gas transmission pipeline, the phase of light transmitted in the optical fiber when external vibration is detected is collected, and at the same time, the light at each position of the current gas transmission pipeline is collected as the change in the distribution state of electromagnetic waves;

[0062] If the phase of light transmitted in the optical fiber fluctuates due to external vibration, or if the distribution state of light as electromagnetic waves at various locations in the current gas transmission pipeline changes, it is inferred that a gas leak has occurred at the current location and the current location is sent to the gas leak detection platform. After receiving the real-time gas leak location, the gas leak detection platform repairs the leak and simultaneously monitors locations of the same type or risk type;

[0063] It should be explained that phase fluctuation can be calculated by measuring the amount of movement or change in the interference fringes; the change in the distribution state of the electromagnetic wave is represented by the change in the distribution waveform. In the prior art, a polarization beam splitter is used to split the incident light into two beams according to different polarization directions, and then the light intensity of the two beams is measured by photodetectors respectively.

[0064] If the phase of light transmitted in the optical fiber does not fluctuate during external vibration, and the distribution state of light as an electromagnetic wave at each position in the current gas transmission pipeline does not change, it is inferred that there is no gas leakage at the current position and monitoring is continued.

[0065] When the present invention is in use, the pipeline position detection and identification unit detects and identifies the pipeline covered by the distributed sensor, and determines whether the gas transmission pipeline has the conditions for leakage during operation based on the detection and identification. If the conditions are met, position detection is performed to evaluate the leakage risk; the sensor detection and control unit detects the optical fiber vibration sensor and reasonably sets the position; after the position setting is completed, the data processing and identification unit processes and identifies the collected data of the optical fiber vibration sensor.

[0066] The preferred embodiments of the present invention disclosed above are intended only to help illustrate the present invention. These preferred embodiments do not exhaustively describe all details, nor do they limit the present invention to specific embodiments. Obviously, many modifications and variations are possible based on the contents of this specification. These embodiments are selected and described in detail in this specification to better explain the principles and practical applications of the present invention, thereby enabling those skilled in the art to better understand and utilize the present invention. The present invention is limited only by the claims and their full scope and equivalents.

Claims

1. A gas leak detection system based on distributed sensor technology, characterized in that: It includes a gas leakage detection platform, wherein the gas leakage detection platform is communicatively connected to a pipeline position detection and identification unit, a sensor detection and control unit, and a data processing and identification unit; The pipeline position detection and identification unit detects and identifies the pipelines covered by the distributed sensors. Based on the detection and identification, it determines whether the gas pipeline has the conditions for leakage during operation. If the conditions are met, it performs position detection and assesses the leakage risk. The process of the pipeline position detection and identification unit is as follows: According to the splicing process of the gas transmission pipeline and the surface texture of the pipeline, the gas transmission pipeline is divided into the overall position and the split position; The overall and split locations are tested for leak conditions, where the leak condition is the energy difference between the inside and outside of the gas pipeline when the gas is being transported. Physical barriers are also set at the gas pipeline locations. When the entire gas transmission pipeline is used as the detection subject, the internal pressure average value of the gas transmission pipeline during the gas transportation period and the non-operation period is obtained. If the internal pressure average value is within the set pressure average value range, it is judged that the risk of pressure deviation in the current gas transmission pipeline is low. Otherwise, it is inferred that the pressure deviation risk is high. The gas leakage detection platform controls the gas transmission of the gas transmission pipeline to adjust the transmission volume or transmission speed. When the internal pressure mean is within the set range, the peak value of the internal pressure mean is used as the comparison pressure value, and combined with the ambient pressure value of the gas transmission pipeline area at the time corresponding to the comparison pressure value, the comparison pressure value and the ambient pressure value are continuously compared starting from this time. When the comparison pressure value is higher than the ambient pressure value, the corresponding moment is marked as the internal strong moment; conversely, when the comparison pressure value is lower than the ambient pressure value, the corresponding moment is marked as the external strong moment; According to the statistics of adjacent comparison moments, if the pressure difference corresponding to the internal strong moment or the external strong moment during the continuous detection period exceeds the pressure difference threshold, or the maximum value of the continuous alternation frequency of the internal strong moment and the external strong moment as adjacent moments exceeds the alternation frequency threshold, then it is inferred that the gas transmission pipeline operation stage during the continuous detection period has the conditions for leakage; conversely, if the pressure difference corresponding to the internal strong moment or the external strong moment during the continuous detection period does not exceed the pressure difference threshold, and the maximum value of the continuous alternation frequency of the internal strong moment and the external strong moment as adjacent moments does not exceed the alternation frequency threshold, then it is inferred that the gas transmission pipeline operation stage during the continuous detection period does not have the conditions for leakage; Sensor detection and control unit, which detects the optical fiber vibration sensor and reasonably sets its position; After the position setting is completed, the data processing and identification unit processes and identifies the collected data of the optical fiber vibration sensor.

2. The gas leak detection system based on distributed sensor technology according to claim 1, characterized in that: Once the conditions for leakage are met, test the overall position and the split position; During the operating period when the conditions for leakage occur, the performance parameters of the physical isolators corresponding to the overall position and the split position of the same type of physical isolators are collected; the floating trend of the performance parameters is obtained based on the specific values ​​of the performance parameters of the physical isolators at each moment. When the floating trend of the performance parameters shows a downward trend, a leakage risk signal is generated and sent to the gas leakage detection platform. When the floating trend of the performance parameters does not show a downward trend, a leakage safety signal is generated and sent to the gas leakage detection platform.

3. The gas leakage detection system based on distributed sensor technology according to claim 2, characterized in that: When there is a risk of leakage, if there is a deviation in the downward trend of the performance parameters corresponding to the overall position and the split position, and the downward trend of the overall position is slower than the downward trend of the split position, a warning protection signal is generated and sent to the gas leakage detection platform; if there is no deviation in the downward trend of the performance parameters corresponding to the overall position and the split position, or the downward trend of the overall position is not slower than the downward trend of the split position, a synchronous warning protection signal is generated and sent to the gas leakage detection platform.

4. The gas leak detection system based on distributed sensor technology according to claim 1, characterized in that: The process of sensor detection control unit is as follows: The overall and split positions are analyzed, and the current environment is simulated using an optical fiber vibration sensor. The fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span corresponding to the optical fiber vibration sensor when internal pipeline deformation occurs are collected. If the fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span corresponding to the fiber optic vibration sensor when the pipeline internal deformation occurs are both within the corresponding span threshold range, it is inferred that the current simulation operation position is suitable for setting up the sensor; If the fiber refractive index fluctuation span corresponding to the pipeline temperature rise stage during gas transportation and the fiber propagation loss span of the fiber optic vibration sensor corresponding to the internal pipeline deformation are not both within the corresponding span threshold ranges, it is inferred that the current simulation operation location is not suitable for sensor installation.

5. The gas leakage detection system based on distributed sensor technology according to claim 4, characterized in that: Mark locations with leakage conditions as leakage risk locations, and calculate the distribution density of leakage risk locations according to the gas transmission pipeline; If the distribution density is higher than the set density threshold, the installation method is: set up a sensor core processor and place it at the center of the location, and install the sensors centrally with the center as the origin. The processor sends the collected data of the sensors in a centralized manner; if the distribution density is lower than the set density threshold, the installation method is: use a single sensor as the main body and cover the corresponding location, and send the real-time collected data in a distributed manner.

6. The gas leakage detection system based on distributed sensor technology according to claim 1, characterized in that: The process of data processing identification unit is as follows: Fiber optic vibration sensors are used to detect various positions in the gas delivery pipeline, and phase change analysis and polarization state change analysis are performed through the collected data. During the operation of the gas delivery pipeline, the phase of light transmitted in the optical fiber when external vibration occurs is collected, and at the same time, the light at various positions in the current gas delivery pipeline is collected as changes in the distribution state of electromagnetic waves.

7. The gas leakage detection system based on distributed sensor technology according to claim 6, characterized in that: If the phase of light transmitted in the optical fiber fluctuates during external vibration, or if the distribution state of light as an electromagnetic wave at various positions in the current gas transmission pipeline changes, it is inferred that a gas leak occurs at the current position, and the current position is sent to the gas leak detection platform; if the phase of light transmitted in the optical fiber does not fluctuate during external vibration, and the distribution state of light as an electromagnetic wave at various positions in the current gas transmission pipeline does not change, it is inferred that no gas leak occurs at the current position, and monitoring is continued.

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