A natural gas pipeline leak detection method, device, equipment, medium and product

Abstract

The application discloses a natural gas pipeline leakage detection method, device, equipment, medium and product. The method applied to a central station comprises the following steps: receiving upstream sound wave signals and downstream sound wave signals detected in a target gas pipeline and sent by a substation; determining an energy value difference array of preset sampling points of the upstream and downstream and a median value of the energy difference of the upstream and downstream according to a preset time window, the upstream sound wave signals and the downstream sound wave signals; determining an upstream leakage detection index and a downstream leakage detection index according to the energy value difference array and the median value of the energy difference of the upstream and downstream; and in response to the upstream leakage detection index and the downstream leakage detection index exceeding a preset threshold value, positioning pipeline leakage according to a detection time point exceeding the preset threshold value. The application effectively improves the accuracy of natural gas pipeline leakage detection and the detection positioning efficiency.

Description

Technical Field

[0001] This application relates to the field of pipeline inspection technology, and in particular to a method, apparatus, equipment, medium and product for detecting leaks in natural gas pipelines. Background Technology

[0002] Long-distance natural gas pipelines traverse vast areas with diverse natural and social environments, making them susceptible to leaks due to landslides, floods, and third-party construction activities. Furthermore, the large diameter and high operating pressure of natural gas pipelines, coupled with the flammable and explosive nature of natural gas, mean that leaks can easily trigger major safety accidents, causing casualties and economic losses.

[0003] Currently, many staff members are focusing on developing automated and intelligent methods for detecting leaks in natural gas pipelines. Improving the efficiency and accuracy of gas pipeline detection has become one of the key research areas for technical personnel in related fields. Summary of the Invention

[0004] This application provides a method, apparatus, equipment, medium, and product for detecting leaks in natural gas pipelines, thereby improving the efficiency and accuracy of natural gas pipeline leak identification.

[0005] According to a first aspect of this application, a method for detecting leaks in a natural gas pipeline is provided, applied at a central station, the method comprising: Receive upstream and downstream acoustic signals detected in the target gas pipeline from the substation; Based on the preset time window, upstream acoustic signal, and downstream acoustic signal, determine the energy value difference array and the median of the upstream and downstream energy difference of the preset sampling points within the preset time length, respectively. Based on the energy value difference array and the median of the upstream and downstream energy differences, the upstream and downstream leakage detection indicators are determined respectively; In response to the leakage detection indicators at the upper and lower levels exceeding the preset thresholds, the pipeline leakage is located based on the detection time when the thresholds are exceeded.

[0006] According to a second aspect of this application, a method for detecting leaks in a natural gas pipeline is provided, applied to a substation, the method comprising: Acoustic wave acquisition devices are deployed at preset locations in the target gas pipeline to acquire upstream and downstream acoustic wave signals in the target gas pipeline. The upstream acoustic signal and downstream acoustic information are sent to the central station.

[0007] According to a third aspect of this application, a natural gas pipeline leak detection device is provided, applied at a central station, the device comprising: The signal receiving module is used to receive the upstream and downstream acoustic signals detected in the target gas pipeline, which are sent by the substation. The differential calculation module is used to determine the energy value difference array and the median of the upstream and downstream energy difference of the upstream and downstream preset sampling points within a preset time length, based on the preset time window, the upstream acoustic signal, and the downstream acoustic signal. The indicator determination module is used to determine the upstream and downstream leakage detection indicators based on the energy value difference array and the median of the upstream and downstream energy difference. The leak detection module is used to locate pipeline leaks based on the time of detection when the upper and lower leak detection indicators exceed preset thresholds.

[0008] According to a fourth aspect of this application, a natural gas pipeline leak detection device is provided, applied to a substation, the device comprising: The signal acquisition module is used to acquire upstream and downstream acoustic signals in the target gas pipeline through an acoustic acquisition device deployed at a preset location in the target gas pipeline. The signal transmission module is used to send upstream acoustic signals and downstream acoustic information to the central station.

[0009] According to a fifth aspect of this application, an electronic device is provided, the electronic device comprising: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to perform the natural gas pipeline leak detection method described in the first and / or second aspects of this application.

[0010] According to a sixth aspect of this application, a computer-readable storage medium is provided, the computer-readable storage medium storing computer instructions for causing a processor to execute and implement the natural gas pipeline leak detection method described in the first aspect embodiment and / or the second aspect embodiment of this application.

[0011] According to a seventh aspect of this application, a computer program product is provided, the computer program product comprising a computer program that, when executed by a processor, implements the natural gas pipeline leak detection method according to the embodiments of the first aspect and / or the second aspect of this application.

[0012] The technical solution of this application relies on upstream and downstream acoustic signals of the pipeline, and combines energy difference and median statistics to construct leak detection indicators. This effectively filters out common noise interference such as pipeline medium flow and equipment vibration, avoiding the problems of false alarms and missed alarms that are prone to occur with traditional single threshold detection, and significantly improving the accuracy of leak identification. Simultaneously, this solution determines the leak status by quantifying and standardizing detection indicators, replacing manual experience-based judgment, and achieving real-time automatic identification of leak faults. Furthermore, it achieves precise location based on the time difference between the two-end signals exceeding limits, eliminating the need for manual full-line inspection and quickly pinpointing the leak location. The overall detection process is highly automated, has strong anti-interference capabilities, balances detection accuracy and response speed, and is suitable for the all-weather stable monitoring needs of pipelines, effectively improving the accuracy and efficiency of natural gas pipeline leak detection and location.

[0013] It should be understood that the description in this section is not intended to identify key or essential features of the embodiments of this application, nor is it intended to limit the scope of this application. Other features of this application will become readily apparent from the following description. Attached Figure Description

[0014] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0015] Figure 1 This is a flowchart of a natural gas pipeline leak detection method applicable to a central station, provided according to Embodiment 1 of this application; Figure 2 This is a flowchart of a natural gas pipeline leak detection method applicable to substations, provided according to Embodiment 2 of this application; Figure 3A This is a schematic diagram of natural gas pipeline leak detection according to Embodiment 3 of this application; Figure 3B This is a schematic diagram of the acoustic signal processing flow according to Embodiment 3 of this application; Figure 4 This is a structural schematic diagram of a natural gas pipeline leak detection device suitable for a central station, provided according to Embodiment 4 of this application; Figure 5 This is a structural schematic diagram of a natural gas pipeline leak detection device applicable to a substation, provided according to Embodiment 5 of this application; Figure 6 This is a schematic diagram of the structure of an electronic device that implements the natural gas pipeline leak detection method of the embodiments of this application. Detailed Implementation

[0016] To enable those skilled in the art to better understand the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present application, and not all embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without creative effort should fall within the scope of protection of the present application.

[0017] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this application are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this application described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0018] Example 1 Figure 1 This application provides a flowchart of a natural gas pipeline leak detection method suitable for a central station, as shown in Embodiment 1. This embodiment is applicable to situations where natural gas pipeline leak detection is performed at a central station. The method can be executed by a flowchart device suitable for natural gas pipeline leak detection at a central station. This flowchart device can be implemented in hardware and / or software and can be configured in an electronic device. Figure 1 As shown, the method includes: S110: Receive the upstream and downstream acoustic signals detected in the target gas pipeline sent by the substation.

[0019] The central station can be a monitoring center for pipeline leaks, acquiring and analyzing acoustic signals uploaded by various substations in real time. Correspondingly, substations can be front-end acquisition devices deployed along the gas pipeline, such as stations and valve chambers, equipped with acoustic acquisition and communication devices, specifically for on-site pipeline signal acquisition and uploading. The target gas pipeline can be the pipeline transporting the gas currently being monitored for leaks; the transported gas can be natural gas, and this application will use a natural gas pipeline as an example for further explanation. The upstream and downstream acoustic signals can be the acoustic signals of the internal medium vibration collected in real time by acoustic sensors at preset acquisition points upstream and downstream of the pipeline by the substations, stored as a continuous time-series sampling data sequence. It is understood that upstream and downstream are relative terms; since the direction of gas transport within the pipeline is fixed, upstream and downstream can be defined along the gas flow direction. Therefore, by setting acoustic detection sensors at multiple preset acquisition points in the target gas pipeline, if a leak occurs at a certain point in the pipeline, the upstream and downstream acoustic signals detected at the two adjacent acquisition points upstream and downstream can be the upstream and downstream acoustic signals, respectively.

[0020] During the routine operation of the target gas pipeline, each substation continuously collects acoustic signals from upstream and downstream of the pipeline and uploads them to the central station in real time. The central station continuously monitors the data transmitted by the substations, receives and stores the raw acoustic signal sequences from upstream and downstream in real time, providing complete and real-time raw data support for subsequent data processing, feature analysis, and leak detection.

[0021] S120. Based on the preset time window, the upstream acoustic signal, and the downstream acoustic signal, determine the energy value difference array and the median of the upstream and downstream energy difference of the preset sampling points within the preset time length.

[0022] The preset time window can be a pre-configured fixed sampling calculation window, quantized by the number of sampling points, used for segmented statistical calculations of discrete acoustic sampling points. The preset time length can be a pre-set data analysis duration, corresponding to a fixed number of continuous sampling points, used to collect valid sample data. The preset sampling point can be a time-series data node collected by the acoustic sensor at a fixed sampling frequency, representing the smallest data unit of the acoustic signal. The energy value difference array can be an ordered data set composed of acoustic energy value difference data from all upstream and downstream sampling points within the preset time length. The median energy difference can be the intermediate characteristic value selected after sorting the energy value difference array data, used to characterize the steady-state difference level of normal pipeline operation and avoid interference from extreme value data.

[0023] The central station retrieves the received upstream and downstream raw acoustic signals and performs batch calculations on all upstream and downstream preset sampling points within the preset time window based on preset time window parameters. First, it calculates the acoustic energy value of each sampling point, then obtains the energy change data through differential calculation, collects them into a differential array, and finally determines the corresponding energy difference median through data filtering, thus completing the conversion of the raw signal into steady-state characteristic data.

[0024] S130. Determine the upstream and downstream leakage detection indicators based on the energy value difference array and the median of the upstream and downstream energy difference.

[0025] Among them, the leakage detection index can be used as reference data to determine whether the target gas pipeline has leaked. It is divided into upstream leakage detection index and downstream leakage detection index, which are used to accurately characterize the degree of abnormal change in the pipeline's acoustic signal. The higher the index value, the greater the risk of pipeline leakage and the more likely there is a leakage.

[0026] The central station uses the energy value difference array output from step S120 and the median energy difference between upstream and downstream as the core calculation basis. Combining the fluctuation characteristics and abnormal change characteristics of the pipeline under normal operating conditions, it generates independent leakage detection indicators for upstream and downstream through comparative calculations, thereby completing the quantitative output of the pipeline operating status and providing the core basis for subsequent threshold determination.

[0027] S140. In response to the leakage detection indicators of the upper and lower parts exceeding the preset threshold, the pipeline leakage is located according to the detection time when the leakage exceeds the preset threshold.

[0028] The preset threshold can be a critical value calibrated based on a large amount of measured data from normal and leaking pipeline conditions, serving as a criterion for distinguishing between normal pipeline operation and leakage faults. The detection time can be a precise timing point where upstream and downstream leakage detection indicators exceed the preset threshold.

[0029] The central station compares the upstream and downstream leakage detection indicators output by S130 with the preset thresholds in real time. If the indicators exceed the limits, it determines that the pipeline has a leakage fault. It simultaneously records the precise detection time when the upstream and downstream indicators exceed the limits. Based on the time difference between the two detection times, combined with parameters such as pipeline length and sound wave propagation speed, it accurately calculates the location of the leak point and completes the leak detection and location.

[0030] The technical solution of this application relies on upstream and downstream acoustic signals of the pipeline, and combines energy difference and median statistics to construct leak detection indicators. This effectively filters out common noise interference such as pipeline medium flow and equipment vibration, avoiding the problems of false alarms and missed alarms that are prone to occur with traditional single threshold detection, and significantly improving the accuracy of leak identification. Simultaneously, this solution determines the leak status by quantifying and standardizing detection indicators, replacing manual experience-based judgment, and achieving real-time automatic identification of leak faults. Furthermore, it achieves precise location based on the time difference between the two-end signals exceeding limits, eliminating the need for manual full-line inspection and quickly pinpointing the leak location. The overall detection process is highly automated, has strong anti-interference capabilities, balances detection accuracy and response speed, and is suitable for the all-weather stable monitoring needs of pipelines, effectively improving the accuracy and efficiency of natural gas pipeline leak detection and location.

[0031] In one optional implementation, the step of S120, which determines the energy difference array and the median of the upstream and downstream energy differences for preset sampling points within a preset time length based on a preset time window, the upstream acoustic signal, and the downstream acoustic signal, may include: S121. Based on the upstream and downstream acoustic signals, calculate the energy values ​​of the upstream and downstream preset sampling points respectively through a preset time window.

[0032] It is understandable that the original acoustic signal is vibration waveform data, which cannot directly reflect changes in the pipeline's operating state and needs to be converted into energy values ​​for signal quantization. This application's embodiment uses a preset time window as the statistical range, performing a squared mean calculation on the acoustic data at each preset sampling point upstream and downstream to quantify the single-point acoustic energy intensity. By iterating through the time window point by point, the standardized energy values ​​of all time-series sampling points can be accurately obtained, eliminating single-point random errors.

[0033] S122. Determine the energy value difference between upstream and downstream based on the energy values ​​of upstream and downstream respectively.

[0034] A single-moment energy value only reflects the instantaneous signal strength and cannot reflect dynamic changes. This application's embodiment highlights signal abrupt changes through differential calculation. Using a preset interval as a reference, the energy values ​​of adjacent time sequences are calculated to obtain the dynamic energy change as the energy value difference. This calculation can effectively amplify the energy abrupt change signal caused by leakage, distinguishing between normal pipeline flow vibrations and abnormal leakage fluctuations.

[0035] S123. Within a preset time period, calculate the energy value difference array between upstream and downstream, and determine the median of the energy difference between upstream and downstream in the energy value difference array between upstream and downstream.

[0036] Continuous sampling points within a preset time period are selected, and all differential data are aggregated to form upstream and downstream energy value difference arrays. The two arrays are then sorted, and the median value of the upstream and downstream energy differences is calculated using a median algorithm. The median value avoids interference from transient noise, equipment vibration, and other abnormal extreme values, accurately representing the steady-state energy difference level under normal pipeline operation.

[0037] For example, the upstream acoustic signal acquired in real time is The downstream acoustic signal is Add window calculation upstream of the first The energy value of each sampling point is: Downstream The energy value of each sampling point is: in, The time sequence number of the sampling point. The window length is the preset time window.

[0038] The difference between the upstream and downstream energy values ​​is calculated separately to obtain the downstream first... The energy difference between each sampling point is divided into: Downstream The energy difference between each sampling point is divided into: Set the preset time length as For the energy difference data, calculate the median for each group of upstream energy difference data. The median of the upstream energy difference group is: The median of the downstream energy value difference fraction group is: In an optional implementation, the step of determining the upstream and downstream leakage detection indicators based on the energy value difference array and the median of the upstream and downstream energy differences in step S130 may include: S131. Determine the peak values ​​of upstream and downstream energy mutations based on the energy value difference array.

[0039] Among them, the energy mutation peak value is the maximum characteristic value of abnormal fluctuations in the pipeline, used to characterize the strongest signal disturbance caused by leakage. Of course, the upstream and downstream energy mutation peak values ​​include both upstream and downstream peak values. By using all the data in the aforementioned energy value difference array as the monitored sample, the maximum value is extracted as the mutation peak value, accurately capturing the maximum abnormal fluctuation signal during pipeline operation.

[0040] S132. Determine the normal fluctuation amplitude of upstream and downstream energy based on the energy value difference array and the median of upstream and downstream energy difference.

[0041] The normal fluctuation amplitude is used to quantify the inherent fluctuation interference under leak-free pipeline conditions, avoiding misjudgment under normal operating conditions. The normal fluctuation level is characterized by calculating the median of the absolute deviations of all differential data from the steady-state median.

[0042] S133. Calculate the ratio of the difference between the peak value of the upstream and downstream energy mutation and the median value of the upstream and downstream energy difference to the normal fluctuation amplitude of the upstream and downstream energy, and determine the upstream and downstream leakage detection indicators.

[0043] Ratio calculations generate standardized detection indicators, eliminating calculation biases caused by differences in operating conditions and equipment. First, the difference between the peak value and the median value is used to eliminate the influence of the steady-state baseline and retain the pure abnormal fluctuation component; then, the ratio is taken with the normal fluctuation amplitude to obtain the dimensionless upstream and downstream leakage detection indicators.

[0044] For example, based on the aforementioned implementation method, the upstream and downstream leakage detection indicators can be determined in the following ways.

[0045] The upstream leakage detection indicators are: The downstream leakage detection indicators are: Understandable, and The numerator represents the difference between the peak value of the abrupt change and the median difference of the vibration, while the denominator represents the amplitude of the normal vibration. In other words, the numerator represents how much the peak value deviates from the normal center when the sound wave is abnormal, while the denominator represents the fluctuation of the sound wave under normal conditions. That is, the ratio calculated by comparing the "abrupt change" and the "normal vibration" is used as a reference value for judging leakage.

[0046] In one optional implementation, the step of locating the pipeline leak based on the detection time exceeding a preset threshold in S140 may include: S141. Determine the time difference between upstream and downstream leak detection based on the detection time.

[0047] When a pipeline leaks, the abnormal acoustic signal generated at the leak point propagates simultaneously upstream and downstream. Due to the different distances between the leak point and the upstream and downstream sensors, there is a time difference in the moments when the sensors at both ends detect the abnormal signal. This step accurately records the detection time when the upstream and downstream detection indicators first exceed the limit. The time difference dt of the bidirectional acoustic propagation is calculated from the time difference, and this time difference is the core dynamic parameter for leak location.

[0048] Therefore, the time difference between the detection of anomalies in the upstream and downstream areas is calculated based on the detection times recorded when the upstream and downstream areas respectively detect the acoustic anomalies.

[0049] S142. Locate pipeline leaks based on time difference, the length of the monitoring section of the target gas pipeline, and the speed of sound propagation in the transported gas.

[0050] For example, based on the aforementioned implementation method, the location of a pipeline leak can be calculated in the following way, when the upstream and downstream detection statistics... , When the threshold is exceeded, a pipeline leak is considered to have occurred, and upstream and downstream detection statistics are recorded. , When the time exceeds a set threshold, the leak location can be determined using the time difference. The location formula is as follows: in, To monitor the length of the pipe section, Let be the speed of sound in the transported gas. The time difference between upstream and downstream leak detection.

[0051] Example 2 Figure 2 This application provides a flowchart of a natural gas pipeline leak detection method applicable to a substation, as described in Embodiment 1. This embodiment is applicable to situations where the substation provides signals and data for detecting pipeline leaks to the central station. The method can be executed by a flowchart device applicable to natural gas pipeline leak detection in a substation. This flowchart device can be implemented in hardware and / or software and can be configured in an electronic device. Figure 1 As shown, the method includes: S210. Acquire upstream and downstream acoustic signals in the target gas pipeline by means of an acoustic acquisition device deployed at a preset location in the target gas pipeline.

[0052] The acoustic wave acquisition device can be used to collect acoustic waves generated in a target gas pipeline. For example, it can consist of an acoustic wave sensor, an acquisition controller, a communication module, and a power supply module. The preset locations can be pre-defined signal acquisition positions within the target gas pipeline. These can be arranged according to the pipeline layout and valve chambers, or a group of acoustic wave detection devices can be set at regular intervals. Of course, the specific arrangement can be set by those skilled in the art based on extensive experimentation or manual experience; this application does not limit this approach. It is understood that multiple acoustic wave acquisition devices will simultaneously acquire acoustic wave signals, acquiring them first and then defining upstream and downstream to obtain the corresponding upstream and downstream acoustic wave signals.

[0053] S220: Send the upstream acoustic signal and downstream acoustic information to the central station.

[0054] After acquiring the acoustic signals from upstream and downstream, the signals are sent to the central station so that the central station can perform leak detection and analysis based on these signals.

[0055] In the technical solution of this application embodiment, multiple substations are used as detection sources, and acoustic wave acquisition devices are deployed to collect acoustic wave signals generated in the target gas pipeline, so as to provide the main station with sufficiently accurate leakage detection basis, which helps to improve the efficiency and accuracy of leakage detection.

[0056] Example 3 Figure 3A This is a schematic diagram of natural gas pipeline leak detection provided in Embodiment 3 of this application. This embodiment is a specific example provided based on the foregoing embodiments and implementation methods. The natural gas pipeline leak detection method illustrated in this application requires the installation of two parts: a leak monitoring substation and a central station. For a long-distance pipeline including 3 stations and 2 valve chambers (see...),... Figure 3A This includes 5 substation systems and 1 central station system in the dispatch room. An example is shown below: The substation system consists of four parts: an acoustic wave sensor, an acoustic wave acquisition module, a communication module, and a power supply module. The acoustic wave acquisition module acquires the data collected by the acoustic wave sensor in real time. The acoustic wave signal sampling rate is 1000Hz, and a synchronous acquisition method is used. After 10 seconds of sampling, the data is packaged and uploaded to the central station system by channel. To ensure time synchronization of data from each substation, the uploaded data needs to include a timestamp; here, the sampling time and sample number of the first sampling point are uploaded together. The format of the uploaded data is shown in Table 1.

[0057] Table 1 In addition, the substation system needs to use satellite calibration or NTP (Network Time Protocol) to synchronize time and maintain time consistency between the substation and the central station.

[0058] The central station system is usually installed in the dispatch room or other places with 24-hour personnel monitoring. It consists of three parts: a data analysis server, a communication module, and a monitoring terminal. The data analysis server receives and analyzes the acoustic signals uploaded by the substations in real time. When it determines that a pipeline leak has occurred, it pushes an alarm to the monitoring terminal to issue an alarm message.

[0059] The core function of the central station system is data analysis; the data processing flow is as follows: Figure 3B : The first step is to receive data.

[0060] It receives data uploaded from sub-sites in real time, parses it, concatenates it by channel, and caches it in memory.

[0061] The second step is to calculate the data energy value of each channel of the substation.

[0062] After each data reception, it is checked whether the data in the buffer has reached 20 seconds. If it has, the data from each substation is grouped together according to the upstream outgoing and downstream incoming acoustic waves for calculation and analysis. For example, the outgoing acoustic signal from station A is... The corresponding downstream acoustic signal is the station B entrance acoustic wave. .

[0063] when When the data length is 20 seconds, window the upstream calculation. The energy value of each sampling point is: Downstream The energy value of each sampling point is: in, The time sequence number of the sampling point. This is the window length, with a value of 1000.

[0064] The third step is to calculate the difference in energy values ​​to determine whether a leak has occurred.

[0065] The difference between the upstream and downstream energy values ​​is calculated separately to obtain the downstream first... The energy difference between each sampling point is divided into: Downstream The energy difference between each sampling point is divided into: Calculate the median of the energy value difference set, where: The median of the upstream energy value difference fractional group is: The median of the downstream energy value difference fraction group is: Upstream Leakage Detection Statistics Downstream Leakage Detection Statistics When the upstream and downstream detection statistics , When the value exceeds the set threshold of 50, a leak is considered to have occurred in the pipeline.

[0066] The fourth step is to locate the leak point.

[0067] Record the times when the upstream and downstream detection statistics exceed the set threshold. , Calculate the time difference between upstream and downstream Calculate the location of the leak and trigger an alarm.

[0068] The method for calculating the location of the leak is as follows: in, To monitor the length of the pipe section; The speed of sound in natural gas is taken as 420 m / s; The time difference between upstream and downstream leak detection.

[0069] Fifth step: Delete the earliest 10 seconds of data in the cache, and repeat the first step above.

[0070] The embodiments provided in this application acquire new acoustic signals inside the pipeline by installing acoustic sensors upstream and downstream. The installation method is simple and can utilize existing pressure gauges and pressure transmitters at the pipeline's pressure tapping points. The system only requires substation acquisition equipment installed at stations and valve chambers, and a data analysis server and monitoring terminals installed at the monitoring center to achieve leakage monitoring of the entire pipeline. Additional monitoring terminals can be added at stations and other locations to achieve segmented or multi-level joint monitoring of leaks. This invention provides an efficient and reliable comprehensive solution for the safe operation of long-distance natural gas pipelines.

[0071] Example 4 Figure 4 This is a schematic diagram of a natural gas pipeline leak detection device provided in Embodiment 4 of this application. This device 400 can be applied to a central station, such as... Figure 4 As shown, the device 400 includes: The signal receiving module 410 is used to receive the upstream and downstream acoustic signals detected in the target gas pipeline sent by the substation; The differential calculation module 420 is used to determine the energy value difference array and the median of the upstream and downstream energy difference of the upstream and downstream preset sampling points within a preset time length, based on the preset time window, the upstream acoustic signal, and the downstream acoustic signal. The indicator determination module 430 is used to determine the upstream and downstream leakage detection indicators based on the energy value difference array and the median of the upstream and downstream energy difference. The leakage detection module 440 is used to locate pipeline leaks based on the detection time when the upper and lower leakage detection indicators exceed the preset thresholds.

[0072] The technical solution of this application relies on upstream and downstream acoustic signals of the pipeline, and combines energy difference and median statistics to construct leak detection indicators. This effectively filters out common noise interference such as pipeline medium flow and equipment vibration, avoiding the problems of false alarms and missed alarms that are prone to occur with traditional single threshold detection, and significantly improving the accuracy of leak identification. Simultaneously, this solution determines the leak status by quantifying and standardizing detection indicators, replacing manual experience-based judgment, and achieving real-time automatic identification of leak faults. Furthermore, it achieves precise location based on the time difference between the two-end signals exceeding limits, eliminating the need for manual full-line inspection and quickly pinpointing the leak location. The overall detection process is highly automated, has strong anti-interference capabilities, balances detection accuracy and response speed, and is suitable for the all-weather stable monitoring needs of pipelines, effectively improving the accuracy and efficiency of natural gas pipeline leak detection and location.

[0073] In one alternative implementation, the indicator determination module 430 may include: The mutation peak determination unit is used to determine the upstream and downstream energy mutation peaks based on the energy value difference array; The jitter amplitude determination unit is used to determine the normal jitter amplitude of upstream and downstream energy based on the energy value difference array and the median of upstream and downstream energy difference, respectively. The detection index determination unit is used to calculate the ratio of the difference between the peak value of the upstream and downstream energy mutation and the median value of the upstream and downstream energy difference to the normal fluctuation amplitude of the upstream and downstream energy, and to determine the upstream and downstream leakage detection index.

[0074] In one alternative embodiment, the leakage detection module 440 may include: The time difference determination unit is used to determine the time difference between upstream and downstream leak detection based on the detection time. The leak location determination unit is used to locate pipeline leaks based on time difference, the length of the monitored section of the target gas pipeline, and the speed of sound propagation in the transported gas.

[0075] In one optional implementation, the difference calculation module 420 may include: The energy value determination unit is used to calculate the energy values ​​of the upstream and downstream preset sampling points respectively through a preset time window based on the upstream and downstream acoustic signals. The energy difference determination unit is used to determine the energy value difference between upstream and downstream based on the energy values ​​of upstream and downstream respectively. The differential median determination unit is used to statistically analyze the energy value difference array between upstream and downstream within a preset time period, and to determine the median of the energy difference between upstream and downstream within the energy value difference array.

[0076] The natural gas pipeline leak detection device provided in this application embodiment can execute the natural gas pipeline leak detection method provided in embodiment one of this application, and has the corresponding functional modules and beneficial effects of executing the natural gas pipeline leak detection method corresponding to embodiment one of this application.

[0077] Example 5 Figure 5 This is a schematic diagram of a natural gas pipeline leak detection device provided in Embodiment 5 of this application. This device 500 can be applied to a substation, such as... Figure 5 As shown, the device 500 includes: The signal acquisition module 510 is used to acquire upstream and downstream acoustic signals in the target gas pipeline through an acoustic acquisition device deployed at a preset position in the target gas pipeline. The signal transmission module 520 is used to send upstream acoustic wave signals and downstream acoustic wave information to the central station.

[0078] In the technical solution of this application embodiment, multiple substations are used as detection sources, and acoustic wave acquisition devices are deployed to collect acoustic wave signals generated in the target gas pipeline, so as to provide the main station with sufficiently accurate leakage detection basis, which helps to improve the efficiency and accuracy of leakage detection.

[0079] Example 6 Figure 6 A schematic diagram of an electronic device 10, which can be used to implement embodiments of this application, is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (such as helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the application described and / or claimed herein.

[0080] like Figure 6 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer program stored in the ROM 12 or loaded from storage unit 18 into the RAM 13. The RAM 13 can also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0081] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0082] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as natural gas pipeline leak detection methods.

[0083] In some embodiments, the natural gas pipeline leak detection method may be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or installed on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the natural gas pipeline leak detection method described above may be performed. Alternatively, in other embodiments, processor 11 may be configured to perform the natural gas pipeline leak detection method by any other suitable means (e.g., by means of firmware).

[0084] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), system-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0085] Computer programs used to implement the methods of this application may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0086] In the context of this application, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium can be, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium can be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on 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 memory), optical fiber, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing.

[0087] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0088] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or middleware components (e.g., application servers), or frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0089] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0090] This application also discloses a computer program product, which includes a computer program that, when executed by a processor, implements the natural gas pipeline leak detection method provided in any embodiment of this application. This program product shares the same inventive concept as the natural gas pipeline leak detection methods disclosed in the embodiments of this application, and therefore will not be described in detail here.

[0091] It should be understood that the various forms of processes shown above can be used to rearrange, add, or delete steps. For example, the steps described in this application can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this application can be achieved, and this is not limited herein.

[0092] The specific embodiments described above do not constitute a limitation on the scope of protection of this application. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this application should be included within the scope of protection of this application.

Claims

1. A method for detecting leaks in natural gas pipelines, characterized in that, Applied to a central station, the method includes: Receive upstream and downstream acoustic signals detected in the target gas pipeline from the substation; Based on the preset time window, the upstream acoustic signal, and the downstream acoustic signal, determine the energy value difference array and the median of the upstream and downstream energy difference of the preset sampling points within the preset time length, respectively. Based on the energy value difference array and the median of the upstream and downstream energy differences, the upstream and downstream leakage detection indicators are determined respectively. In response to the leakage detection index exceeding a preset threshold, the pipeline leakage is located based on the detection time when the leakage exceeds the preset threshold.

2. The method according to claim 1, characterized in that, The step of determining upstream and downstream leakage detection indicators based on the energy value difference array and the median of the upstream and downstream energy differences includes: Based on the energy value difference array, determine the peak values ​​of upstream and downstream energy abrupt changes; Based on the energy value difference array and the median of the upstream and downstream energy differences, the normal fluctuation amplitude of upstream and downstream energy is determined respectively; The difference between the peak value of the upstream and downstream energy mutation and the median value of the upstream and downstream energy difference are calculated as a ratio to the normal fluctuation amplitude of the upstream and downstream energy to determine the upstream and downstream leakage detection index.

3. The method according to claim 1, characterized in that, The step of locating the pipeline leak based on the detection time exceeding the preset threshold includes: Based on the detection time, determine the time difference between upstream and downstream leak detection; The pipeline leak is located based on the time difference, the length of the monitored section of the target gas pipeline, and the speed of sound propagation in the transported gas.

4. The method according to claim 1, characterized in that, The step of determining the energy difference array and the median of the upstream and downstream energy differences of preset sampling points within a preset time length based on a preset time window, the upstream acoustic signal, and the downstream acoustic signal includes: Based on the upstream acoustic signal and the downstream acoustic signal, the energy values ​​of the upstream and downstream preset sampling points are calculated respectively through a preset time window; Based on the energy values ​​of the upstream and downstream, the energy value difference between the upstream and downstream is determined respectively; Within the preset time length, the energy value difference array between upstream and downstream is statistically analyzed, and the median of the upstream and downstream energy difference array is determined.

5. A method for detecting leaks in natural gas pipelines, characterized in that, Applied to a substation, the method includes: The upstream and downstream acoustic signals in the target gas pipeline are acquired by an acoustic acquisition device deployed at a preset location in the target gas pipeline. The upstream acoustic signal and the downstream acoustic information are sent to the central station.

6. A natural gas pipeline leak detection device, characterized in that, Applied to a central station, the device includes: The signal receiving module is used to receive the upstream and downstream acoustic signals detected in the target gas pipeline, which are sent by the substation. The differential calculation module is used to determine the energy value difference array and the median of the upstream and downstream energy differences of the upstream and downstream preset sampling points within a preset time length, based on a preset time window, the upstream acoustic signal, and the downstream acoustic signal. The indicator determination module is used to determine the upstream and downstream leakage detection indicators based on the energy value difference array and the median of the upstream and downstream energy differences, respectively. The leakage detection module is used to locate the pipeline leak based on the detection time when the upper and lower leakage detection indicators exceed the preset threshold.

7. A natural gas pipeline leak detection device, characterized in that, Applied to a substation, the device includes: The signal acquisition module is used to acquire the upstream and downstream acoustic signals in the target gas pipeline through an acoustic acquisition device deployed at a preset position in the target gas pipeline. The signal transmission module is used to send the upstream acoustic wave signal and the downstream acoustic wave information to the central station.

8. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, the computer program being executed by the at least one processor to enable the at least one processor to perform the natural gas pipeline leak detection method of any one of claims 1-4, and / or, to perform the natural gas pipeline leak detection method of claim 5.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that cause a processor to execute and implement the natural gas pipeline leak detection method of any one of claims 1-4, and / or the natural gas pipeline leak detection method of claim 5.

10. A computer program product, characterized in that, The computer program product includes a computer program that, when executed by a processor, implements the natural gas pipeline leak detection method according to any one of claims 1-4, and / or implements the natural gas pipeline leak detection method according to claim 5.

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