Natural gas leakage detection method and device, electronic equipment and storage medium

Abstract

The embodiment of the invention provides a natural gas leakage detection method and device, electronic equipment and a storage medium. The natural gas leakage detection method comprises the steps that all leakage areas of natural gas in a station are recognized; directionally transmitting an ultrasonic detection signal to each leakage area, and calculating the position information of each leakage area according to the echo time of the ultrasonic detection signal in each direction; calculating the natural gas concentration of the corresponding leakage area according to the gas temperature and the gas molecular weight of each leakage area; and displaying the position information and the natural gas concentration of each leakage area in a detection map of the station. According to the embodiment of the invention, through automatic and remote monitoring technologies, the exposure time of personnel on site is reduced, the safety risk is remarkably reduced, and powerful support is provided for emergency rescue work through accurate monitoring and visualization means.

Description

Technical Field

[0001] The embodiments of the present invention relate to the technical field of natural gas detection, and in particular, to a method, device, electronic device, and storage medium for detecting natural gas leakage. Background Art

[0002] Natural gas is a clean energy source and involves long-distance transportation through pipelines during its use. During transportation, natural gas needs to pass through multiple stations and valve chambers. Especially in scenarios with complex process equipment such as distribution stations, if natural gas leakage occurs, it is necessary to quickly detect the leakage range to determine the safe area.

[0003] Currently, the commonly used methods for detecting natural gas leakage mainly involve on-site operations by station personnel wearing air respirators and combustible gas detectors. There are significant safety hazards, low detection efficiency, and limited detected information, which is not conducive to the development of emergency rescue work. Summary of the Invention

[0004] The embodiments of the present invention provide a method, device, electronic device, and storage medium for detecting natural gas leakage, which can reduce the safety risks of on-site personnel and provide strong support for emergency rescue work.

[0005] In a first aspect, the method for detecting natural gas leakage provided by the embodiments of the present invention includes:

[0006] Identifying each leakage area of natural gas in the station;

[0007] Directionally emitting ultrasonic detection signals to each leakage area, and calculating the position information of each leakage area according to the echo time of the ultrasonic detection signals in each direction;

[0008] Calculating the natural gas concentration of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area;

[0009] Displaying the position information and natural gas concentration of each leakage area in the detection map of the station.

[0010] In a second aspect, the device for detecting natural gas leakage provided by the embodiments of the present invention includes:

[0011] An identification module, configured to identify each leakage area of natural gas in the station;

[0012] A position calculation module, configured to directionally emit ultrasonic detection signals to each leakage area, and calculate the position information of each leakage area according to the echo time of the ultrasonic detection signals in each direction;

[0013] A concentration calculation module, configured to calculate the natural gas concentration of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area;

[0014] A display module for displaying the location information and natural gas concentration of each leakage area in the detection map of the station.

[0015] In a third aspect, the electronic device provided by an embodiment of the present invention includes a memory, a processor, and a computer program stored on the memory and executable on the processor. When the processor executes the program, it implements the natural gas leakage detection method according to any embodiment of the present invention.

[0016] In a fourth aspect, the computer-readable storage medium provided by an embodiment of the present invention stores a computer program, and when the program is executed by a processor, it implements the natural gas leakage detection method according to any embodiment of the present invention.

[0017] In the embodiments of the present invention, by identifying each leakage area of natural gas in the station and calculating the location information of the leakage area using the echo time of the ultrasonic detection signal, the leakage range can be determined quickly and accurately. Compared with traditional on-site operations, this method greatly improves the detection efficiency and reduces the exposure risk of on-site personnel; by measuring the gas temperature and gas molecular weight in the leakage area and calculating the natural gas concentration of the corresponding leakage area, this concentration calculation method based on physical parameters can provide more accurate leakage information and help evaluate the severity of the leakage more scientifically; displaying the location information and natural gas concentration of the leakage area in the detection map of the station provides a more comprehensive detection result. This visualization method makes the leakage information clear at a glance, facilitates on-site personnel to make decisions quickly, and improves the efficiency of the emergency rescue work. That is, the embodiments of the present invention reduce the exposure time of personnel on-site and significantly reduce the safety risk through automation and remote monitoring technologies, and provide strong support for the emergency rescue work through precise monitoring and visualization means. BRIEF DESCRIPTION OF THE DRAWINGS

[0018] In order to more clearly illustrate the technical solutions of the present invention, the drawings required for use in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of the present invention, and therefore should not be regarded as limiting the scope. For those of ordinary skill in the art, other related drawings can be obtained based on these drawings without creative efforts.

[0019] Figure 1 is a flowchart of the natural gas leakage detection method provided by an embodiment of the present invention;

[0020] Figure 2 is another flowchart of the natural gas leakage detection method provided by an embodiment of the present invention;

[0021] Figure 3 is an example diagram of ultrasonic distance measurement provided by an embodiment of the present invention;

[0022] Figure 4 It is a schematic structural diagram of a natural gas leakage detection device provided by an embodiment of the present invention;

[0023] Figure 5 It is a schematic structural diagram of an electronic device provided by an embodiment of the present invention. Detailed implementation manners

[0024] In order to enable those skilled in the art to better understand the solution of the present invention, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only a part of the embodiments of the present invention, rather than all the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those of ordinary skill in the art without creative efforts shall fall within the protection scope of the present invention.

[0025] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings 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 under appropriate circumstances so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "comprising" and "having" and any variations thereof are intended to cover non-exclusive inclusion. For example, a process, method, system, product or device that includes a series of steps or units does not necessarily have to be limited to those steps or units clearly listed, but may include other steps or units not clearly listed or inherent to these processes, methods, products or devices.

[0026] Figure 1 It is a schematic flowchart of a natural gas leakage detection method provided by an embodiment of the present invention. The natural gas leakage detection method provided by the embodiment of the present invention is applicable to detecting natural gas leakage in places such as a detection station. The natural gas leakage detection method can be executed by the natural gas leakage detection device provided by the embodiment of the present invention, and the device can be implemented in a software and / or hardware manner. In a specific embodiment, the device can be integrated in an electronic device, and the electronic device can be a computer, a server, etc. The following embodiments will take the integration of the natural gas leakage detection device in an electronic device as an example for description. Refer to Figure 1 , the natural gas leakage detection method of this embodiment may include the following steps:

[0027] Step 110, identify each leakage area of natural gas in the station.

[0028] The natural gas leakage area refers to the area where natural gas escapes into the environment due to leakage incidents in natural gas pipelines, stations or related equipment. These areas usually have a relatively high natural gas concentration and may vary depending on the location of the leakage point, the leakage volume and environmental conditions (such as wind direction, temperature).

[0029] Specifically, various monitoring devices can be deployed in natural gas stations, such as laser gas sensors, ultrasonic sensors, fiber optic sensors, etc., to monitor the leakage of natural gas in real time using multiple monitoring devices. These monitoring devices collect data by monitoring parameters such as gas concentration, pressure changes, and acoustic signals and transmit the data to electronic devices. The electronic devices analyze this data to identify the occurrence of leakage incidents. Once a leakage incident is detected, the location of the leakage point is identified through a preset algorithm, and the scope of the leakage area is determined.

[0030] Step 120: Directionally transmit ultrasonic detection signals to each leakage area, and calculate the location information of each leakage area based on the echo time of the ultrasonic detection signals in each direction.

[0031] Ultrasonic waves are high-frequency sound waves that propagate in a straight line in a homogeneous medium. When ultrasonic waves encounter the interface of different media (such as the interface between leaked gas and air), reflection occurs. In the natural gas leakage area, the leaked gas will form an area with changing density near the leakage point. The ultrasonic signal will encounter different media interfaces (such as the interface between leaked gas and air) in these areas, resulting in reflection. The gas turbulence and density changes near the leakage point will enhance the reflected signal, making it easier to detect.

[0032] The ultrasonic detection signal can be a high-frequency acoustic signal used to detect natural gas leakage. These signals will produce reflection or scattering near the leakage point, forming detectable echoes. The echo time refers to the time interval from the emission of the ultrasonic signal to the reception of its echo. By measuring the echo time, the distance traveled by the ultrasonic signal can be calculated, thereby determining the location of the leakage point.

[0033] Specifically, ultrasonic transmitters can be used to transmit ultrasonic detection signals in all directions around natural gas stations or pipelines. These signals have high-frequency characteristics and can produce reflection near the leakage point. The ultrasonic sensor receives the echo signal reflected from the leakage area. The gas turbulence at the leakage point will generate ultrasonic signals with specific frequencies, and these signals are the strongest near the leakage point. By measuring the time interval (echo time) between the transmitted signal and the received echo signal, the distance traveled by the ultrasonic signal can be calculated. Based on the calculated distance and direction information, the specific location of the leakage area can be determined. This location information can be used to generate a visualization map of the leakage area to help operators quickly locate the leakage point.

[0034] There are multiple leakage areas, and each leakage area is in a different direction. The transmission direction of the ultrasonic detection signal can be determined according to the direction of each leakage area, so as to transmit the ultrasonic detection signal to each leakage area directionally to detect the position information of each leakage area.

[0035] By transmitting the ultrasonic detection signal to each leakage area directionally and calculating the position information of the leakage area according to the echo time, the propagation and reflection characteristics of ultrasonic waves are utilized, and combined with multi-directional measurement, high-precision leakage positioning is achieved. This method not only improves the efficiency of leakage detection, but also enhances the safety and reliability of detection.

[0036] Step 130, calculate the natural gas concentration of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area.

[0037] The gas temperature refers to the temperature of natural gas in the leakage area. Temperature affects the volume and density of the gas, and thus affects the concentration calculation. The gas molecular weight refers to the average molecular weight of natural gas, usually in grams per mole (g / mol). Methane (CH4) is the main component of natural gas, and its molecular weight is about 16 g / mol. The natural gas concentration can refer to the content of methane in the leakage area, usually expressed in volume percentage (%VOL) or mass concentration (mg / m 3 )

[0038] According to the ideal gas law, the volume of a gas is related to temperature and pressure. In the leakage area, the gas temperature affects its volume and density, and thus affects the concentration. At the same time, the gas molecular weight determines the mass of gas per unit volume and affects the concentration calculation. By measuring the gas temperature and molecular weight in the leakage area, the natural gas concentration can be calculated quickly. This method can provide accurate concentration information, help to quickly evaluate the severity of the leakage, and provide a scientific basis for emergency response.

[0039] Step 140, display the position information and natural gas concentration of each leakage area in the detection map of the station.

[0040] The detection map of the station refers to a map used to record and display the leakage detection results in the natural gas station. It usually includes the layout of the station, the location of equipment, the position information of the leakage area and the concentration distribution, etc. The position information refers to the specific coordinates or directions of the leakage area, which can be calculated according to the echo situation of the ultrasonic detection signal.

[0041] The layout of the station and the equipment location information can be utilized to generate a detailed detection map, which will serve as the basis for recording and presenting the leakage detection results. The location information of the leakage area is calculated based on the echo time of the ultrasonic detection signal, and the specific location of each leakage area is displayed on the detection map. The natural gas concentration is calculated based on the gas temperature and molecular weight of the leakage area, and the concentration information is displayed at the corresponding leakage area location. Through the display on the detection map, the location and concentration distribution of the leakage area are visually presented. This visualization method helps on-site personnel quickly understand the leakage situation and thus take corresponding emergency measures.

[0042] In this embodiment, by identifying each leakage area of natural gas in the station and using the echo time of the ultrasonic detection signal to calculate the location information of the leakage area, the leakage range can be determined quickly and accurately. Compared with traditional on-site operations, this method greatly improves the detection efficiency and reduces the exposure risk of on-site personnel; by measuring the gas temperature and gas molecular weight of the leakage area and calculating the natural gas concentration of the corresponding leakage area, this concentration calculation method based on physical parameters can provide more accurate leakage information and help evaluate the severity of the leakage more scientifically; displaying the location information and natural gas concentration of the leakage area in the detection map of the station provides a more comprehensive detection result. This visualization method makes the leakage information clear at a glance, facilitating on-site personnel to make decisions quickly and improving the efficiency of emergency rescue work. That is, the embodiment of the present invention reduces the exposure time of personnel on-site through automation and remote monitoring technologies, significantly reducing the safety risk, and provides strong support for emergency rescue work through precise monitoring and visualization means.

[0043] The natural gas leakage detection method provided by the embodiment of the present invention will be further described below. As Figure 2 shown, the method of this embodiment includes:

[0044] Step 210, identify each leakage area of natural gas in the station.

[0045] Ideal gas law:

[0046] PV=nRT (1)

[0047] Wherein, P represents pressure, V represents gas volume, n is the amount of substance, R is the universal gas constant, and T represents gas temperature (usually represented by absolute temperature). Since natural gas is usually transported under pressure during transportation and the pressure is much greater than the standard atmospheric pressure, when natural gas leaks and the pressure decreases while other parameters remain basically unchanged, according to the ideal gas law formula, the gas temperature T will also decrease accordingly. That is, when natural gas leaks, the gas temperature will change.

[0048] However, objects / media emit electromagnetic radiation at any temperature, and the intensity and wavelength distribution of the radiation depend on the temperature of the object / media. The higher the temperature of the object / media, the stronger the infrared radiation emitted. Therefore, an infrared signal detector can be used to detect the infrared radiation signal of the medium, convert the infrared radiation into an electrical signal, and thus measure the temperature of the medium.

[0049] That is, the temperature detection results of the infrared signal detector can be used to identify each leakage area of natural gas at the station. Specifically, an infrared signal detector can be used to detect the gas temperature at the station and generate a temperature distribution map of the station based on the temperature detection results; set a temperature threshold according to the ambient temperature; identify the area in the temperature distribution map that matches the temperature threshold to obtain the target map area; and identify the actual area corresponding to the target map area at the station as the leakage area. The infrared signal detector measures the gas temperature by receiving the infrared radiation of different gases. When natural gas leaks, its temperature change will affect the intensity and wavelength of the infrared radiation, so it can be detected by the detector.

[0050] For the temperature distribution map, different temperature regions can be represented by different colors, and the temperature change of the leaked gas will form a color region different from the surrounding environment on the temperature distribution map. Since the contrast between the temperature change of the leaked gas and the ambient temperature varies in different seasons, in summer, the ambient temperature is usually higher than the temperature of the leaked gas. When natural gas leaks, the gas temperature further decreases. Therefore, the leakage area corresponds to the region with a lower temperature in the temperature distribution map, and the region with a lower temperature can be distinguished and displayed in a different color from other regions. In winter, the ambient temperature is usually lower than the temperature of the leaked gas. When natural gas leaks, although the gas temperature decreases, it is still higher than the ambient temperature. Therefore, the leakage area corresponds to the region with a higher temperature in the temperature distribution map, and the region with a higher temperature can be distinguished and displayed in a different color from other regions.

[0051] The temperature threshold can be set according to the ambient temperature. If in summer, the ambient temperature is higher than the temperature of the leaked gas, a smaller temperature threshold can be set, and the region corresponding to the points where the gas temperature is lower than the temperature threshold is determined as the target map area. If in winter, the ambient temperature is lower than the temperature of the leaked gas, a higher temperature threshold can be set, and the region corresponding to the points where the gas temperature is higher than the temperature threshold is determined as the target map area.

[0052] Since it is necessary to ensure that the temperature distribution map clearly shows the range of the leakage area and retain the boundary characteristics while removing noise, a bilateral filtering mode can be used here to filter the temperature distribution map, taking into account both the spatial distance and pixel differences. The specific calculation method can be as follows:

[0053]

[0054] Among them, I'(x) is the pixel value after filtering, that is, the pixel value at position x in the image after bilateral filtering. W(x) is the normalization factor to ensure that the pixel value after filtering is within a reasonable range. I(x i ) is the neighborhood pixel value, which is the original pixel value of each pixel point x within the neighborhood covered by the filter kernel i . S is the neighborhood covered by the filter kernel, indicating that when performing bilateral filtering, the set of all pixel points within the neighborhood centered on the current pixel point is considered. G s (||x - x i ||) is the spatial weight function, representing the weight of the positional distance between pixels. This function is usually used to measure the influence of spatial distance on the filtering result. The closer the pixels are, the greater the influence on the current pixel. G r (|I(x) - I(x i )|) is the intensity weight function, representing the weight of the pixel value difference. This function is used to measure the influence of pixel value difference on the filtering result. The smaller the difference between pixels, the greater the influence on the current pixel.

[0055] Use an infrared signal detector to detect the infrared radiation and temperature changes of the leaked gas, and generate a temperature distribution map. By analyzing the color changes in the temperature distribution map and setting a temperature threshold in combination with seasonal characteristics, the leakage area can be effectively identified. This method can quickly and accurately locate the leakage point, improving the efficiency and safety of leakage detection.

[0056] The gas density in the natural gas leakage area will change with factors such as the duration of leakage, the size of the leakage opening, the leakage pressure, the wind speed, and the ambient temperature. That is, the gas density in the leakage area is variable, while the gas density in the non-leakage area can generally be considered relatively stable. When light passes through an area with variable density (such as a natural gas leakage area), the light will deflect, resulting in a shaded area with light and dark contrast on the image. This light and dark contrast reflects the change in gas density. The more obvious the density change, the stronger the contrast. By capturing the image of the light and dark distribution of these lights, a shadow map can be generated.

[0057] That is, the leakage areas of natural gas in the station can also be identified through the shadow map of the station. Specifically, the shadow map of the station can be obtained; the areas in the shadow map where the shadow contrast exceeds the contrast threshold are identified to obtain the target map areas; and the actual areas corresponding to the target map areas in the station are identified as the leakage areas.

[0058] The shadow map generation process can be as follows: Use parallel laser light to irradiate each area of the station, and set a photosensitive detector opposite each area for imaging to capture the light and dark distribution image after projection. The more obvious the density change, the stronger the contrast. Through image processing, the optical signal is converted into an electrical signal, which is enhanced and filtered by an amplifier circuit and then converted into a digital signal through analog-to-digital conversion. Finally, the digital signal is processed to generate a shadow map.

[0059] A contrast threshold can be set according to environmental conditions and the characteristics of the leaked gas. In the shadow map, identify the areas where the shadow contrast exceeds the contrast threshold. These areas correspond to the leakage areas, and identify the actual areas corresponding to these target map areas in the station as leakage areas. By generating a shadow map and identifying the high-contrast areas therein, the leakage area can be quickly located. This method utilizes the refraction principle of light in a medium with uneven density and combines image processing technology to efficiently detect and locate the leakage area.

[0060] Furthermore, in order to make the generated temperature distribution map and shadow map more intuitive and easier for on-site personnel to view, further image processing can be carried out. The visualization effect of the density or temperature distribution can be optimized by enhancing the contrast or applying numerical simulation. In the processing of the temperature distribution map, identify and distinguish according to seasonal characteristics: in summer, mark the areas with lower temperature as the possible leakage range; in winter, mark the areas with higher temperature as the possible leakage range. This seasonal adjustment method improves the accuracy of leakage detection and on-site operability. For the shadow map, the imaging effect depends on the density change of the gas. The more obvious the density change, the stronger the contrast. The shadow map can be sharpened to filter out low-frequency information and retain high-frequency components to highlight the edges, so as to facilitate the determination of the leakage boundary. The final result can integrate the position information and concentration information on the map, which is convenient for on-site personnel to obtain the leakage situation in real time, so as to determine the next rescue measures. In addition, the leakage area detection can be continuously carried out, and the display effects of the temperature distribution map and shadow map can be updated according to the real-time detection results to achieve real-time leakage monitoring.

[0061] Step 220, directionally constrain the emitted ultrasonic detection signal through an ultrasonic transducer array to obtain detection beams in each direction.

[0062] The ultrasonic transducer array is an array composed of multiple ultrasonic transducers, which can emit and receive ultrasonic signals. Through the design of the array, directional control and beam focusing can be achieved. Directional constraint means that by controlling the emission direction of the ultrasonic transducers, the ultrasonic signal is concentrated in a specific direction, which can be achieved by adjusting the arrangement of the transducer array and the phase of the emitted signal. The detection beam refers to the ultrasonic signal in a fixed direction formed by directional constraint.

[0063] An ultrasonic transducer array can be composed of multiple independent piezoelectric wafers, which can be arranged in a specific pattern (such as a linear array, a two-dimensional array, etc.). By adjusting the transmission phase and amplitude of each wafer in the transducer array, the propagation direction of the ultrasonic signal can be controlled. This directivity control enables the ultrasonic signal to be concentrated in a specific direction, forming a detection beam. The detection beam in each direction can cover a specific area within the field station, for detecting the location of the leakage area. By means of detection beams in multiple directions, simultaneous monitoring of multiple leakage areas within the field station can be achieved.

[0064] Step 230: After encoding and differentiating the directions of the detection beams in each direction, send them to the corresponding leakage area.

[0065] Encoding refers to the process of marking or differentiating the detection beams in each direction. Through encoding, it can be ensured that each beam can be accurately identified during transmission and reception, thus differentiating signals in different directions. Barker coding can be used for beam encoding.

[0066] Through the ultrasonic transducer array, direction constraints are imposed on the transmitted ultrasonic signal to form detection beams in multiple directions, and each beam can cover a specific area within the field station. The detection beams in each direction are encoded to give them unique identifiers. Encoding can be achieved by adjusting the phase, frequency or amplitude of the beam, ensuring that each beam can be accurately identified during transmission and reception.

[0067] Step 240: Calculate the distance from the corresponding leakage area to the observation point according to the echo time of the ultrasonic detection signal in each direction.

[0068] The echo signals of the ultrasonic detection signal in each direction can be received. For the same ultrasonic detection signal, there may be one echo signal or two echo signals. If there is one echo signal, the echo time is the first echo time; if there are two echo signals, the echo time is the first echo time and the second echo time.

[0069] Specifically, when the echo time is the first echo time, the distance from the corresponding leakage area to the observation point can be calculated according to the first echo time and the propagation speed of ultrasonic waves in air; when the echo time is the first echo time and the second echo time, the distance from the corresponding leakage area to the observation point can be calculated according to the first echo time, the second echo time, the propagation speed of ultrasonic waves in air and the propagation speed of ultrasonic waves in natural gas.

[0070] The first echo time refers to the time it takes for an ultrasonic signal to travel from transmission to the first reception of the reflected echo, which typically corresponds to the time for the ultrasonic signal to travel through the air to the leakage area and back. The second echo time refers to the time when the ultrasonic signal is reflected again and received after the first reflection, which may occur when the ultrasonic signal passes through the leakage area and reflects on an interface further away. The propagation speed of ultrasonic waves in air is typically about 340 m / s, but it may vary slightly due to factors such as temperature and humidity. The propagation speed of ultrasonic waves in natural gas is usually lower than that in air, and the specific value depends on the composition and pressure of the natural gas. The distance from the leakage area to the observation point refers to the straight-line distance between the leakage point and the ultrasonic sensor. By measuring the echo time and the sound speed, this distance can be calculated.

[0071] When the echo time is only the first echo time, it indicates that the ultrasonic signal travels through the air to the leakage area and back. At this time, the following formula can be used to calculate the distance d1 from the leakage area to the observation point:

[0072]

[0073] where v0 represents the propagation speed of ultrasonic waves in air, and t0 represents the first echo time.

[0074] When the echo time includes the first echo time and the second echo time, it means that the ultrasonic signal travels through the air to the leakage area and then is reflected and returns again. At this time, the propagation speed of ultrasonic waves in natural gas needs to be considered. The following formula can be used to calculate the distance d2 from the leakage area to the observation point:

[0075]

[0076] where v1 represents the propagation speed of ultrasonic waves in air, and t1 represents the second echo time.

[0077] As Figure 3 shown, the boundary points 1 and 2 of the leakage area are in the same direction. The boundary point 1 is closer to the observation point. The ultrasonic detection signal emitted from the observation point echoes after reaching the boundary point 1 of the leakage area, which is the first echo, and echoes again after reaching the boundary point 2 of the leakage area, which is the second echo. Two echo times can be obtained from the two echoes, and the distance from this leakage area to the observation point can be calculated based on the two echo times.

[0078] By measuring the first echo time and the second echo time, and combining the propagation speeds of ultrasonic waves in air and natural gas, the distance from the leakage area to the observation point can be calculated more accurately. This method can improve the accuracy of leakage detection and is especially suitable for complex leakage scenarios.

[0079] Step 250: Determine the location information of the corresponding leakage area by combining the distances from each leakage area to the observation point and the directions of each leakage area.

[0080] The direction of the leakage area refers to the azimuth of the leakage point relative to the observation point. Through the directional emission and reception of the ultrasonic transducer array, the specific direction of the leakage area can be determined. The location information refers to the specific location of the leakage area in the station, including the distance and direction. By combining the distance and direction information, the leakage area can be accurately located.

[0081] Step 260: Calculate the gas sound speed of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area.

[0082] The gas temperature refers to the temperature of the natural gas in the leakage area, usually expressed in Kelvin (K) or Celsius (°C). The temperature affects the gas sound speed. The gas molecular weight refers to the average molecular weight of natural gas, usually expressed in kilograms per mole (kg / mol) or grams per mole (g / mol). The smaller the molecular weight, the greater the sound speed. The gas sound speed refers to the speed at which sound waves propagate in the gas, usually expressed in meters per second (m / s). The sound speed is affected by the temperature, molecular weight, and specific heat ratio (adiabatic index) of the gas.

[0083] The gas temperature of the leakage area can be measured using a temperature sensor and converted to absolute temperature. The average value of the gas temperatures at each point in the leakage area can be calculated, and the gas temperature T of the leakage area can be represented by the calculated average value. The gas temperatures at each point in the leakage area can also be clustered, and the gas temperature T of the leakage area can be represented by the gas temperature at the cluster center. Determine its molecular weight M according to the composition of natural gas (such as methane content). M is proportional to the methane concentration. The main component of natural gas is methane (CH4), and its molecular weight is about 16 g / mol. Use the ideal gas sound speed formula to calculate the gas sound speed c of the leakage area. The calculation formula is as follows:

[0084]

[0085] Among them, γ is the specific heat ratio, which is about 1.4 for air and natural gas. R is the universal gas constant, about 8.314 J / (mol·K).

[0086] By measuring the gas temperature of the leakage area and determining the gas molecular weight, the gas sound speed of the leakage area can be calculated using the ideal gas sound speed formula. This method can provide important physical parameters for leakage detection and location, thereby improving the accuracy and reliability of detection.

[0087] Step 270: Substitute the gas sound speeds of each leakage area into the mapping model for mapping calculation to obtain the natural gas concentration of the corresponding leakage area. The mapping model is a model that maps the gas sound speed to the natural gas concentration.

[0088] The mapping model is established through experiments or theoretical derivations and can calculate the concentration of natural gas based on the sound velocity. The natural gas concentration refers to the content of natural gas in the leakage area, usually expressed in volume percentage (%VOL) or mass concentration (mg / m 3 ). The mapping model can be as follows:

[0089] Concentration = f(sound velocity); (6)

[0090] where f is the mapping function and can be obtained by fitting experimental data.

[0091] Substitute the measured sound velocity of the gas into the mapping model to calculate the natural gas concentration in the corresponding leakage area.

[0092] By measuring the sound velocity of the gas in the leakage area and substituting it into the mapping model, the natural gas concentration in the leakage area can be obtained. This method can quickly and accurately evaluate the severity of the leakage and provide a scientific basis for emergency response.

[0093] Step 280: Display the location information and natural gas concentration of each leakage area in the detection map of the station.

[0094] The layout of the station and the location information of the equipment can be used to generate a detailed detection map, which will serve as the basis for recording and presenting the leakage detection results. Based on the location information of the leakage area calculated from the echo time of the ultrasonic detection signal, the specific location of each leakage area is displayed on the detection map. Based on the natural gas concentration calculated from the gas temperature and molecular weight in the leakage area, the concentration information is displayed at the corresponding leakage area location. Through the display on the detection map, the location and concentration distribution of the leakage area are visually presented. This visualization method helps on-site personnel quickly understand the leakage situation and thus take corresponding emergency measures.

[0095] By displaying the location information and natural gas concentration of the leakage area in the detection map of the station, the results of the leakage detection can be visually presented. This method not only improves the efficiency of leakage detection but also enhances the on-site personnel's understanding and response ability to the leakage situation.

[0096] In this embodiment, by identifying each leakage area of natural gas at the station and calculating the position information of the leakage area using the echo time of the ultrasonic detection signal, the leakage range can be determined quickly and accurately. Compared with traditional on-site operations, this method greatly improves the detection efficiency and reduces the exposure risk of on-site personnel. By measuring the gas temperature and gas molecular weight of the leakage area and calculating the natural gas concentration of the corresponding leakage area, this concentration calculation method based on physical parameters can provide more accurate leakage information and help evaluate the severity of the leakage more scientifically. Displaying the position information and natural gas concentration of the leakage area in the detection map of the station provides a more comprehensive detection result. This visualization method makes the leakage information clear at a glance, facilitating on-site personnel to make decisions quickly and improving the efficiency of emergency rescue work. That is, the embodiment of the present invention reduces the exposure time of personnel on-site and significantly reduces the safety risk through automation and remote monitoring technologies, and provides strong support for emergency rescue work through precise monitoring and visualization means.

[0097] Figure 4 It is a structural schematic diagram of a natural gas leakage detection device provided by an embodiment of the present invention. This device is applicable to execute the natural gas leakage detection method provided by the embodiment of the present invention, such as Figure 4 shown, this device may specifically include:

[0098] An identification module 401, configured to identify each leakage area of natural gas at the station;

[0099] A position calculation module 402, configured to emit ultrasonic detection signals in a direction to each leakage area, and calculate the position information of each leakage area according to the echo time of the ultrasonic detection signal in each direction;

[0100] A concentration calculation module 403, configured to calculate the natural gas concentration of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area;

[0101] A display module 404, configured to display the position information and natural gas concentration of each leakage area in the detection map of the station.

[0102] In one embodiment, the identification module 401 identifies each leakage area of natural gas at the station, including:

[0103] Detect the gas temperature of the station and generate a temperature distribution map of the station according to the temperature detection result;

[0104] Set a temperature threshold according to the ambient temperature;

[0105] Identify the area in the temperature distribution map that matches the temperature threshold to obtain the target map area;

[0106] Identify the actual area corresponding to the target map area in the station as the leakage area.

[0107] In one embodiment, the recognition module 401 recognizes each leakage area of natural gas at the station, including:

[0108] Obtain the shadow map of the station;

[0109] Identify the area in the shadow map where the shadow contrast exceeds the contrast threshold to obtain the target map area;

[0110] Identify the actual area corresponding to the target map area at the station as the leakage area.

[0111] In one embodiment, the position calculation module 402 directionally emits ultrasonic detection signals to each leakage area, including:

[0112] Perform direction constraint on the emitted ultrasonic detection signals through the ultrasonic transducer array to obtain detection beams in each direction;

[0113] Encode and distinguish the detection beams in each direction and then send them to the corresponding leakage area.

[0114] In one embodiment, the position calculation module 402 calculates the position information of each leakage area according to the echo time of the ultrasonic detection signals in each direction, including:

[0115] Calculate the distance from the corresponding leakage area to the observation point according to the echo time of the ultrasonic detection signals in each direction;

[0116] Combine the distance from each leakage area to the observation point and the direction of each leakage area to determine the position information of the corresponding leakage area.

[0117] In one embodiment, the position calculation module 402 calculates the distance from the corresponding leakage area to the observation point according to the echo time of the ultrasonic detection signals in each direction, including:

[0118] When the echo time is the primary echo time, calculate the distance from the corresponding leakage area to the observation point according to the primary echo time and the propagation speed of ultrasonic waves in the air;

[0119] When the echo time is the primary echo time and the secondary echo time, calculate the distance from the corresponding leakage area to the observation point according to the primary echo time, the secondary echo time, the propagation speed of ultrasonic waves in the air, and the propagation speed of ultrasonic waves in natural gas.

[0120] In one embodiment, the concentration calculation module 403 calculates the natural gas concentration of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area, including:

[0121] Calculate the gas sound speed of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area;

[0122] Substitute the gas sound speeds of each leakage area into the mapping model to obtain the natural gas concentration of the corresponding leakage area. The mapping model is a model that maps the gas sound speed to the natural gas concentration.

[0123] Those skilled in the art can clearly understand that for the convenience and conciseness of description, only the above division of each functional module is used as an example. In practical applications, the above functions can be allocated to different functional modules according to needs, that is, the internal structure of the device is divided into different functional modules to complete all or part of the functions described above. For the specific working process of the above-described functional modules, reference can be made to the corresponding process in the foregoing method embodiments, and details are not described herein again.

[0124] The device according to the embodiment of the present invention can quickly and accurately determine the leakage range by identifying the leakage areas of natural gas at the station and calculating the position information of the leakage area using the echo time of the ultrasonic detection signal. Compared with the traditional on-site operation, this method greatly improves the detection efficiency and reduces the exposure risk of on-site personnel. By measuring the gas temperature and gas molecular weight of the leakage area and calculating the natural gas concentration of the corresponding leakage area, this concentration calculation method based on physical parameters can provide more accurate leakage information, which helps to more scientifically evaluate the severity of the leakage. Displaying the position information and natural gas concentration of the leakage area in the detection map of the station provides a more comprehensive detection result. This visualization method makes the leakage information clear at a glance, facilitating on-site personnel to make decisions quickly and improving the efficiency of emergency rescue work. That is, the embodiment of the present invention reduces the exposure time of personnel on site through automation and remote monitoring technologies, significantly reduces the safety risk, and provides strong support for emergency rescue work through precise monitoring and visualization means.

[0125] The embodiment of the present invention further provides an electronic device, including a memory, a processor, and a computer program stored on the memory and executable on the processor. When the processor executes the program, it implements the natural gas leakage detection method provided in any of the above embodiments.

[0126] The embodiment of the present invention further provides a computer-readable medium, on which a computer program is stored. When the program is executed by a processor, it implements the natural gas leakage detection method provided in any of the above embodiments.

[0127] Next, refer to Figure 5 , which shows a schematic structural diagram of a computer system 500 of an electronic device suitable for implementing the embodiment of the present invention. Figure 5 The electronic device shown is only an example and should not bring any limitations to the functions and usage scope of the embodiment of the present invention.

[0128] As Figure 5As shown, computer system 500 includes a central processing unit (CPU) 501, which can perform various appropriate actions and processes according to a program stored in a read-only memory (ROM) 502 or a program loaded from a storage section 508 into a random access memory (RAM) 503. In the RAM 503, various programs and data required for the operation of the computer system 500 are also stored. The CPU 501, ROM 502, and RAM 503 are connected to each other via a bus 504. An input / output (I / O) interface 505 is also connected to the bus 504.

[0129] The following components are connected to the I / O interface 505: an input section 506 including a keyboard, a mouse, etc.; an output section 507 including a cathode ray tube (CRT), a liquid crystal display (LCD), etc. and a speaker, etc.; a storage section 508 including a hard disk, etc.; and a communication section 509 including a network interface card such as a LAN card, a modem, etc. The communication section 509 performs communication processing via a network such as the Internet. A drive 510 is also connected to the I / O interface 505 as needed. A removable medium 511, such as a magnetic disk, an optical disk, a magneto-optical disk, a semiconductor memory, etc., is installed on the drive 510 as needed so that a computer program read from it can be installed into the storage section 508 as needed.

[0130] Specifically, according to an embodiment disclosed by the present invention, the process described above with reference to the flowchart can be implemented as a computer software program. For example, an embodiment disclosed by the present invention includes a computer program product, which includes a computer program carried on a computer-readable medium, and the computer program contains program codes for performing the method shown in the flowchart. In such an embodiment, the computer program can be downloaded and installed from a network via the communication section 509, and / or installed from the removable medium 511. When the computer program is executed by a central processing unit (CPU) 501, the above functions defined in the system of the present invention are executed.

[0131] It should be noted that the computer-readable medium shown in the present invention can be a computer-readable signal medium, a computer-readable storage medium, or any combination of the above two. The computer-readable storage medium can be, for example, but not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination of the above. More specific examples of the computer-readable storage medium can include, but are not limited to: an electrical connection having one or more wires, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the above. In the present invention, the computer-readable storage medium can be any tangible medium that contains or stores a program, and this program can be used by or in conjunction with an instruction execution system, apparatus, or device. In the present invention, the computer-readable signal medium can include a data signal propagated in a baseband or as part of a carrier wave, which carries the computer-readable program code. Such a propagated data signal can take various forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination of the above. The computer-readable signal medium can also be any computer-readable medium other than the computer-readable storage medium, and this computer-readable medium can send, propagate, or transmit a program for use by or in conjunction with an instruction execution system, apparatus, or device. The program code contained on the computer-readable medium can be transmitted by any suitable medium, including but not limited to: wireless, wire, optical cable, RF, etc., or any suitable combination of the above.

[0132] The flowcharts and block diagrams in the accompanying drawings illustrate the possible architectures, functions, and operations of systems, methods, and computer program products according to various embodiments of the present invention. In this regard, each block in the flowchart or block diagram can represent a module, a program segment, or a part of code, and the above module, program segment, or part of code contains one or more executable instructions for implementing the specified logical function. It should also be noted that in some alternative implementations, the functions marked in the blocks may occur in a different order than that marked in the accompanying drawings. For example, two consecutive blocks shown may actually be executed substantially in parallel, and they may sometimes be executed in the reverse order, depending on the functions involved. It should also be noted that each block in the block diagram or flowchart, as well as the combination of blocks in the block diagram or flowchart, can be implemented by a dedicated hardware-based system for performing the specified functions or operations, or can be implemented by a combination of dedicated hardware and computer instructions.

[0133] The modules and / or units involved in the embodiments of the present invention can be implemented in software or in hardware. The described modules and / or units can also be provided in a processor. For example, it can be described as: a processor includes an identification module, a position calculation module, a concentration calculation module, and a display module. Among them, the names of these modules do not constitute a limitation to the module itself in some cases.

[0134] As another aspect, the present invention also provides a computer-readable medium, which can be included in the device described in the above embodiments; or it can exist alone without being assembled into the device. The above computer-readable medium carries one or more programs. When the above one or more programs are executed by such a device, the device includes:

[0135] Identify the various leakage areas of natural gas at the station;

[0136] Directly emit ultrasonic detection signals to the various leakage areas, and calculate the position information of the various leakage areas according to the echo time of the ultrasonic detection signals in each direction;

[0137] Calculate the natural gas concentration of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area;

[0138] Display the position information and natural gas concentration of the various leakage areas in the detection map of the station.

[0139] The technical solution of the embodiments of the present invention can quickly and accurately determine the leakage range by identifying the various leakage areas of natural gas at the station and calculating the position information of the leakage areas using the echo time of the ultrasonic detection signals. Compared with the traditional on-site operation, this method greatly improves the detection efficiency and reduces the exposure risk of on-site personnel; by measuring the gas temperature and gas molecular weight of the leakage area and calculating the natural gas concentration of the corresponding leakage area, this concentration calculation method based on physical parameters can provide more accurate leakage information, which helps to more scientifically evaluate the severity of the leakage; displaying the position information and natural gas concentration of the leakage area in the detection map of the station provides a more comprehensive detection result. This visualization method makes the leakage information clear at a glance, facilitating on-site personnel to make decisions quickly and improving the efficiency of emergency rescue work. That is, the embodiments of the present invention reduce the exposure time of personnel on site and significantly reduce the safety risk through automation and remote monitoring technologies, and provide strong support for emergency rescue work through precise monitoring and visualization means.

[0140] It should be understood that the various forms of processes shown above can be used, with steps reordered, added or deleted. For example, the steps described in the present invention can be executed in parallel, sequentially or in different orders, as long as the desired results of the technical solution of the present invention can be achieved, and no limitations are imposed herein.

[0141] It should be noted that in the technical solution of the present disclosure, in aspects such as the collection, gathering, updating, analysis, processing, use, transmission, storage, etc. of the user's personal information, they all comply with the provisions of relevant laws and regulations, are used for legal purposes, and do not violate public order and good customs. Necessary measures are taken for the user's personal information to prevent illegal access to the user's personal information data, and to safeguard the security of the user's personal information, network security and national security.

[0142] The above specific implementation manners do not constitute a limitation on the protection scope of the present invention. Those skilled in the art should understand that various modifications, combinations, sub - combinations and substitutions can occur depending on design requirements and other factors. Any modifications, equivalent substitutions and improvements made within the spirit and principles of the present invention shall be included within the protection scope of the present invention.

Claims

1. A natural gas leak detection method, characterized in that: include: Identify various areas of natural gas leakage at the station; Directively transmit ultrasonic detection signals to each leakage area, and calculate the location information of each leakage area according to the echo time of the ultrasonic detection signal in each direction; Calculate the natural gas concentration in the corresponding leakage area based on the gas temperature and gas molecular weight of each leakage area; The location information and natural gas concentration of each leakage area are displayed in the detection map of the site.

2. The method according to claim 1, characterized in that Identify various areas of natural gas leakage at the station, including: Detect the gas temperature of the station and generate a temperature distribution map of the station based on the temperature detection results; Set the temperature threshold according to the ambient temperature; Identify the area in the temperature distribution map that matches the temperature threshold and obtain the target map area; The actual area corresponding to the target map area in the station is identified as the leakage area.

3. The method according to claim 1, characterized in that Identify various areas of natural gas leakage at the station, including: Get the shadow map of the station; Identify the area in the shadow image where the shadow contrast exceeds the contrast threshold, and obtain the target image area; The actual area corresponding to the target map area in the station is identified as the leakage area.

4. The method according to claim 1, characterized in that: Directed emission of ultrasonic detection signals to various leakage areas, including: The transmitted ultrasonic detection signal is directionally constrained through an ultrasonic transducer array to obtain a detection beam in each direction; The detection beam in each direction is encoded and sent to the corresponding leakage area.

5. The method according to claim 1, characterized in that The location information of each leakage area is calculated based on the echo time of the ultrasonic detection signal in each direction, including: Calculate the distance from the corresponding leakage area to the observation point according to the echo time of the ultrasonic detection signal in each direction; The location information of the corresponding leakage area is determined by combining the distance from each leakage area to the observation point and the direction of each leakage area.

6. The method according to claim 5, characterized in that The distance from the corresponding leakage area to the observation point is calculated based on the echo time of the ultrasonic detection signal in each direction, including: When the echo time is one echo time, the distance from the corresponding leakage area to the observation point is calculated according to the one echo time and the propagation speed of ultrasonic waves in the air; When the echo time is the first echo time and the second echo time, the distance from the corresponding leakage area to the observation point is calculated according to the first echo time, the second echo time, the propagation speed of ultrasound in air and the propagation speed of ultrasound in natural gas.

7. The method according to any one of claims 1 to 6, characterized in that: The natural gas concentration in the corresponding leakage area is calculated based on the gas temperature and gas molecular weight of each leakage area, including: Calculate the gas sound velocity in the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area; The gas sound velocity of each leakage area is substituted into the mapping model for mapping calculation to obtain the natural gas concentration of the corresponding leakage area. The mapping model is a model that maps and calculates the gas sound velocity into the natural gas concentration.

8. A natural gas leak detection device, characterized in that: include: Identification module, used to identify various leakage areas of natural gas at the station; A position calculation module is used to transmit ultrasonic detection signals to each leakage area in a direction and calculate the position information of each leakage area according to the echo time of the ultrasonic detection signal in each direction; A concentration calculation module, used to calculate the natural gas concentration of the corresponding leakage area according to the gas temperature and gas molecular weight of each leakage area; The display module is used to display the location information and natural gas concentration of each leakage area in the detection map of the station.

9. An electronic device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the program, the natural gas leakage detection method according to any one of claims 1 to 7 is implemented.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the program is executed by a processor, the natural gas leakage detection method according to any one of claims 1 to 7 is implemented.

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