Method, device, system, terminal and medium for determining pipeline leakage impact area

Abstract

The present application provides a method, device, system, terminal and medium for determining the area affected by pipeline leakage, and belongs to the field of natural gas pipeline network safety and measurement technology. The present application provides a first relationship calculation model for determining the radius of the area affected by natural gas pipeline leakage, and then after obtaining the wind speed information of the environment in which the pipeline where the leakage occurs, the volume fraction information of the sulfur-containing components in the natural gas transported in the pipeline, the correction coefficient information of the operating pressure and diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section, respectively, through the first relationship calculation model and the second relationship calculation model, based on the corresponding information, the first radius information and the second radius information are determined, and then the target radius information, that is, the radius of the area affected by the natural gas pipeline leakage is determined, without using a Gaussian model to determine the radius information, thereby improving the accuracy of the determined area affected by the leakage of the sour natural gas pipeline.

Description

Technical Field

[0001] The present application relates to the field of natural gas pipeline network safety and measurement technology, and in particular to a method, device, system, terminal and medium for determining an area affected by a pipeline leakage. Background Art

[0002] As a clean energy source, natural gas has been used more and more widely in industrial production and residents' lives. Since natural gas extracted from the mining area generally contains sulfur (usually in the form of hydrogen sulfide), before use, the sour natural gas needs to be transported to the processing plant through a natural gas pipeline for treatment to obtain natural gas that can be used safely. During the transmission process, if a sour natural gas pipeline leaks, it will cause a serious poisoning accident. Therefore, in the actual operation of sour natural gas pipelines, it is of great significance to reasonably determine the potential impact radius of hydrogen sulfide poisoning and determine its impact range to ensure the safe operation of sour natural gas pipelines.

[0003] At present, when determining the radius information of the potential impact area of ​​sour natural gas pipeline leakage, the Gaussian model is mainly used to determine the superposition of the volume fractions of sour natural gas puffs and plumes at different times, so as to characterize the radius information of the potential impact area caused by hydrogen sulfide poisoning due to sour natural gas pipeline leakage.

[0004] In the above implementation process, the Gaussian model is generally used for diffusion analysis of neutral gases, but hydrogen sulfide is a heavy gas, and the accuracy of the potential impact area of ​​hydrogen sulfide poisoning determined by this method is low. Summary of the invention

[0005] The embodiment of the present application provides a method, device, system, terminal and medium for determining the impact area of ​​pipeline leakage, which can improve the accuracy of determining the potential impact area caused by sulfur-containing gas poisoning caused by leakage of sulfur-containing natural gas pipeline. The technical solution is as follows:

[0006] In one aspect, a method for determining a pipeline leakage impact area is provided, the method comprising:

[0007] Obtaining wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed;

[0008] Determine the first radius information through a first relationship calculation model based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section;

[0009] Determine the second radius information by using the second relationship calculation model according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section;

[0010] Based on the first radius information and the second radius information, target radius information is determined, where the target radius information is used to indicate the radius of an affected area when a leak occurs in the pipeline to be processed.

[0011] In a possible implementation, the first relationship calculation model is:

[0012] r1=[0.016ln(u)+0.024]x 1.5 dp 0.5 δ

[0013] Among them, r1 is the first radius information, u is the wind speed information, x is the volume fraction information of the sulfur-containing component, d is the pipeline outer diameter information, p is the maximum allowable pressure information of the pipe section, and δ is the correction coefficient information of the operating pressure and the pipe diameter.

[0014] In a possible implementation, the second relationship calculation model is:

[0015]

[0016] Among them, r2 is the second radius information, d is the pipeline outer diameter information, and p is the maximum allowable pressure information of the pipe section.

[0017] In a possible implementation manner, the determining the target radius information based on the first radius information and the second radius information includes:

[0018] The largest radius information between the first radius information and the second radius information is determined as the target radius information.

[0019] In a possible implementation, the process of obtaining wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed includes:

[0020] Sending an information acquisition request to the server, the information acquisition request is used to obtain the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section;

[0021] Receive the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section returned by the server.

[0022] In one aspect, a device for determining a pipeline leakage impact area is provided, the device comprising:

[0023] An acquisition module is used to acquire wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed;

[0024] A determination module, configured to determine the first radius information based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section through a first relationship calculation model;

[0025] The determination module is further used to determine the second radius information according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a second relationship calculation model;

[0026] The determination module is further used to determine target radius information based on the first radius information and the second radius information, where the target radius information is used to indicate the radius of an affected area when a leak occurs in the pipeline to be processed.

[0027] In a possible implementation, the first relationship calculation model is:

[0028] r1=[0.016ln(u)+0.024]x 1.5 dp 0.5 δ

[0029] Among them, r1 is the first radius information, u is the wind speed information, x is the volume fraction information of the sulfur-containing component, d is the pipeline outer diameter information, p is the maximum allowable pressure information of the pipe section, and δ is the correction coefficient information of the operating pressure and the pipe diameter.

[0030] In a possible implementation, the second relationship calculation model is:

[0031]

[0032] Among them, r2 is the second radius information, d is the pipeline outer diameter information, and p is the maximum allowable pressure information of the pipe section.

[0033] In a possible implementation, the determination module is used to determine the largest radius information between the first radius information and the second radius information as the target radius information.

[0034] In a possible implementation, the acquisition module is used to send an information acquisition request to a server, where the information acquisition request is used to acquire the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the outer diameter information of the pipeline, and the maximum allowable pressure information of the pipe section;

[0035] Receive the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section returned by the server.

[0036] In one aspect, a system for determining a pipeline leakage impact area is provided, the system comprising:

[0037] The server is used to obtain wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur-containing components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipe section of the pipeline to be processed; and send the wind speed information, volume fraction information of the sulfur-containing components, correction coefficient information of the operating pressure and pipe diameter, pipeline outer diameter information, and maximum allowable pressure information of the pipe section to the terminal;

[0038] The terminal is used to receive the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section; determine the first radius information based on the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section through a first relationship calculation model; determine the second radius information according to the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section through a second relationship calculation model; determine the target radius information based on the first radius information and the second radius information, and the target radius information is used to indicate the radius of the affected area when the pipeline to be treated leaks;

[0039] The terminal is also used to issue an alarm based on the target radius information.

[0040] On the one hand, a terminal is provided, which includes one or more processors and one or more memories, wherein the one or more memories store at least one program code, and the program code is loaded and executed by the one or more processors to implement the operations performed by the method for determining the pipeline leakage affected area.

[0041] On the one hand, a computer-readable storage medium is provided, in which at least one program code is stored, and the program code is loaded and executed by a processor to implement the operations performed by the method for determining the pipeline leakage affected area.

[0042] In one aspect, a computer program product or a computer program is provided, the computer program product or the computer program comprising a computer program code, the computer program code being stored in a computer-readable storage medium. A processor of a terminal reads the computer program code from the computer-readable storage medium, and the processor executes the computer program code to implement the operations performed by the method for determining the pipeline leakage affected area.

[0043] The solution provided by the present application provides a first relationship calculation model for determining the radius of the area affected by a natural gas pipeline leakage, and then after obtaining the wind speed information of the environment in which the leaking pipeline is located, the volume fraction information of the sulfur-containing component in the natural gas transported in the pipeline, the correction coefficient information of the operating pressure and diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section, the first radius information and the second radius information are determined based on the corresponding information through the first relationship calculation model and the second relationship calculation model respectively, and then the target radius information, that is, the radius of the area affected by the natural gas pipeline leakage is determined, without using a Gaussian model to determine the radius information, thereby improving the accuracy of the determined area affected by the sour natural gas pipeline leakage. BRIEF DESCRIPTION OF THE DRAWINGS

[0044] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0045] Figure 1 It is a flow chart of a method for determining a pipeline leakage impact area provided in an embodiment of the present application;

[0046] Figure 2 It is a flow chart of a method for determining a pipeline leakage impact area provided in an embodiment of the present application;

[0047] Figure 3 It is a two-dimensional schematic diagram of a physical model of pipeline leakage provided in an embodiment of the present application;

[0048] Figure 4 This is a cloud diagram of the concentration distribution of sour natural gas under different sulfur component volume fraction conditions provided in an embodiment of the present application;

[0049] Figure 5 This is a cloud diagram of the concentration distribution of sulfur-containing natural gas at different times provided in an embodiment of the present application;

[0050] Figure 6This is a cloud diagram of the concentration distribution of sulfur-containing natural gas under different wind speed conditions provided in an embodiment of the present application;

[0051] Figure 7 This is a comparison diagram of potential impact radius under different operating pressures and pipe diameters provided in an embodiment of the present application;

[0052] Figure 8 This is a schematic diagram of a hydrogen sulfide volume fraction correction curve provided in an embodiment of the present application;

[0053] Fig. 9 is a schematic diagram of a wind speed correction curve provided in an embodiment of the present application;

[0054] Fig.10 It is a structural schematic diagram of a system for determining a pipeline leakage impact area provided in an embodiment of the present application;

[0055] Fig.11 It is a structural schematic diagram of a device for determining a pipeline leakage impact area provided in an embodiment of the present application;

[0056] Fig.12 It is a structural diagram of a terminal provided in an embodiment of the present application. DETAILED DESCRIPTION

[0057] In order to make the objectives, technical solutions and advantages of the present application clearer, the implementation methods of the present application will be further described in detail below in conjunction with the accompanying drawings.

[0058] The embodiment of the present application provides a method for determining the pipeline leakage impact area in the field of natural gas pipeline safety and measurement technology, which is specifically used for the potential impact assessment of poisoning caused by leakage of sulfur-containing natural gas pipelines. The relevant technical personnel upload the volume fraction information of the sulfur-containing components in the natural gas transported by each pipeline, the correction coefficient information of the operating pressure and pipe diameter of each pipeline, the pipeline outer diameter information of each pipeline, and the maximum allowable pressure information of the pipe section of each pipeline to the server, so that the terminal obtains the volume fraction information of the sulfur-containing components in the natural gas transported by the pipeline to be processed, the correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, the pipeline outer diameter information of the pipeline to be processed, and the maximum allowable pressure information of the pipe section of the pipeline to be processed uploaded by the relevant technical personnel from the server, and obtains the wind speed information of the environment of the pipeline to be processed obtained by the server from the wind speed sensor near the leakage point or the server of the weather forecast department, and then determines the impact area when the pipeline to be processed leaks based on the obtained information.

[0059] Figure 1 is a flow chart of a method for determining a pipeline leakage impact area provided in an embodiment of the present application, see Figure 1 , the method comprising:

[0060] 101. The terminal obtains wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed.

[0061] 102. The terminal determines the first radius information through a first relationship calculation model based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section.

[0062] 103. The terminal determines the second radius information according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a second relationship calculation model.

[0063] 104. The terminal determines target radius information based on the first radius information and the second radius information, where the target radius information is used to indicate the radius of an affected area when a leak occurs in the pipeline to be processed.

[0064] The solution provided in the embodiment of the present application provides a first relationship calculation model for determining the radius of the area affected by the leakage of a natural gas pipeline, and then after obtaining the wind speed information of the environment in which the leaking pipeline is located, the volume fraction information of the sulfur-containing component in the natural gas transported in the pipeline, the correction coefficient information of the operating pressure and diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section, the first radius information and the second radius information are determined based on the corresponding information through the first relationship calculation model and the second relationship calculation model respectively, and then the target radius information, that is, the radius of the area affected by the leakage of the natural gas pipeline is determined, without using a Gaussian model to determine the radius information, thereby improving the accuracy of the determined area affected by the leakage of the sour natural gas pipeline.

[0065] In a possible implementation, the first relationship calculation model is:

[0066] r1=[0.016ln(u)+0.024]x 1.5 dp 0.5 δ

[0067] Among them, r1 is the first radius information, u is the wind speed information, x is the volume fraction information of the sulfur-containing component, d is the pipeline outer diameter information, p is the maximum allowable pressure information of the pipe section, and δ is the correction coefficient information of the operating pressure and the pipe diameter.

[0068] In a possible implementation, the second relationship calculation model is:

[0069]

[0070] Among them, r2 is the second radius information, d is the pipeline outer diameter information, and p is the maximum allowable pressure information of the pipe section.

[0071] In a possible implementation manner, the determining the target radius information based on the first radius information and the second radius information includes:

[0072] The largest radius information between the first radius information and the second radius information is determined as the target radius information.

[0073] In a possible implementation, the process of obtaining wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed includes:

[0074] Sending an information acquisition request to the server, the information acquisition request is used to obtain the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section;

[0075] Receive the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section returned by the server.

[0076] Figure 2 is a flow chart of a method for determining a pipeline leakage impact area provided in an embodiment of the present application, see Figure 2 , the method comprising:

[0077] 201. The terminal sends an information acquisition request to the server, where the information acquisition request is used to obtain wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipe section of the pipeline to be processed.

[0078] It should be noted that the terminal detects the leakage of each pipeline in real time. When a leak is detected in any pipeline, the leaking pipeline is determined as the pipeline to be processed, and the location information of the leakage point on the pipeline is obtained. Based on the identification of the pipeline to be processed and the location information of the leakage point, an information acquisition request is sent to the server, and the information acquisition request carries the identification of the pipeline to be processed and the location information of the leakage point.

[0079] Among them, the main sulfur-containing component in the sour natural gas is hydrogen sulfide. Optionally, the sour natural gas also includes other sulfur-containing components, which is not limited in the embodiments of the present application.

[0080] 202. The server sends the acquired wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section to the terminal.

[0081] It should be noted that the server is associated with a pipeline information database, which is used to store the volume fraction information of sulfur components in the natural gas transported by each pipeline, the correction coefficient information of the operating pressure and diameter of each pipeline, the outer diameter information of each pipeline, and the maximum allowable pressure information of each pipeline section uploaded by relevant technicians based on the identification of each pipeline. The server is also connected to each wind speed sensor on the pipeline through a wired network or a wireless network, such as the fourth generation mobile communication technology (4G network), or connected to the server of the weather forecast department through a wired network or a wireless network, so as to obtain the wind speed information of the environment at each location on the pipeline.

[0082] In a possible implementation, the server responds to the received information acquisition request, and obtains the wind speed information of the environment in which the leakage point on the pipeline to be processed is located, the volume fraction information of the sulfur-containing components in the natural gas transported by the pipeline to be processed, the correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, the pipeline outer diameter information of the pipeline to be processed, and the maximum allowable pressure information of the pipe section corresponding to the leakage point on the pipeline to be processed according to the identifier of the pipeline to be processed carried in the information acquisition request and the location information of the leakage point on the pipeline to be processed, and then sends the obtained information to the terminal.

[0083] The correction coefficient information of operating pressure and pipe diameter corresponding to different operating pressures and different pipe diameters is shown in Table 1 below:

[0084] Table 1

[0085]

[0086] 203. The terminal receives the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section returned by the server.

[0087] 204. The terminal determines the first radius information through a first relationship calculation model based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section.

[0088] In one possible implementation, the terminal inputs the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipeline, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section into a first relationship calculation model, and outputs the first radius information.

[0089] It should be noted that the first relationship calculation model refers to the following formula (1):

[0090] r1=[0.016ln(u)+0.024]x 1.5 dp 0.5 δ (1)

[0091] Among them, r1 is the first radius information (in meters, m), u is the wind speed information (in meters / second, m / s), x is the volume fraction information of the sulfur-containing component, d is the outer diameter information of the pipeline (in millimeters, mm), p is the maximum allowable pressure information of the pipe section (in megapascals, MPa), and δ is the correction coefficient information of the operating pressure and the pipe diameter.

[0092] It should be noted that the first relationship calculation model is obtained by optimizing the second relationship calculation model. The process of obtaining the first relationship calculation model is described in step 205 below and will not be described in detail here.

[0093] 205. The terminal determines the second radius information according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a second relationship calculation model.

[0094] In a possible implementation, the terminal inputs the pipeline outer diameter information and the maximum allowable pressure information of the pipe section into a second relationship calculation model, and outputs the second radius information.

[0095] It should be noted that the second relationship calculation model is shown in the following formula (2):

[0096]

[0097] Among them, r2 is the second radius information (in meters, m), d is the outer diameter information of the pipeline (in millimeters, mm), and p is the maximum allowable pressure information of the pipe section (in megapascals, MPa).

[0098] It should be noted that the second relationship calculation model is obtained by simulating and analyzing the potential impact range of poisoning caused by sulfur components (for example, hydrogen sulfide) when a sulfur-containing natural gas pipeline leaks under different conditions using fire and explosion (FLACS) numerical simulation software. Among them, when using FLACS software for simulation analysis, it is mainly completed through the steps of front-end computer plan-aided design (CASD) modeling, meshing, simulation parameter setting, model solving, and post-flow (FLOWVIS) result processing. The following introduces each step and the related contents involved:

[0099] 1. Mathematical Model

[0100] The diffusion of sour natural gas in the air after leakage belongs to non-steady turbulent motion, so the Reynolds average pseudo-compression (NS) relationship calculation model is selected as the main control relationship calculation model, in which the relationship calculation model involved includes the mass conservation equation, momentum conservation equation and energy conservation equation. The mass conservation equation, momentum conservation equation and energy conservation equation are respectively shown in the following formulas (3) to (5):

[0101]

[0102] Where ρ is the density (in kilograms per cubic meter, kg / m 3 ), t is time (in seconds, s), u is speed (in meters per second, m / s), S m is the mass exchange between the continuous and discrete phases and any custom mass sources.

[0103]

[0104] Where t is time (in seconds, s), ρ is density (in kilograms per cubic meter, kg / m 3 ), u is the velocity (in meters per second, m / s), p is the static pressure (in Pascals, Pa), τ is the stress tensor, g is the gravitational force, and F is the external body force.

[0105]

[0106] Where ρ is the density (in kilograms per cubic meter, kg / m 3 ), T is temperature (in Kelvin, K), t is time (in seconds, s), u is velocity (in meters per second, m / s), k is the heat transfer coefficient of the fluid (in watts per square meter degrees Celsius, w / (m 2 ℃)), c p is the specific heat capacity (in kilojoules / kilograms·degrees Celsius, kJ / (kg·℃)), S T It is a sticky loose item.

[0107] (2) Physical model and boundary conditions

[0108] The sour natural gas pipeline rupture (full diameter leakage) is used as the leakage simulation scenario, and the emergency shut-off valve is closed 30 seconds after the sour natural gas pipeline leaks. The mixed gas continues to diffuse, and the farthest distance where the volume fraction of hydrogen sulfide in the downwind direction can reach 0.03% is taken as the potential impact radius of poisoning.

[0109] Assume that the calculation areas in the x, y, and z axes are 0-200m, 0-1000m, and 0-500m respectively, and the coordinates of the leakage point are (100, 50, 0.3). In the boundary conditions, set the wind direction to the positive direction of the y axis, the atmospheric stability to D, and the temperature to 20°C. Consider the vertical and horizontal leakage. The physical model of the leakage scene is shown in the two-dimensional schematic diagram. Figure 3 , Figure 3 It is a two-dimensional schematic diagram of a physical model of pipeline leakage provided in an embodiment of the present application.

[0110] 3. Grid Division

[0111] In order to reduce the amount of calculation and speed up the solution of the relational calculation model while ensuring accuracy, the grid size near the leak in each coordinate axis direction is encrypted to 1.5m / grid, and other areas are extended using the Stretch command, ultimately resulting in a total of 54120 grids.

[0112] 4. Simulation parameter conditions

[0113] The most important factors affecting the leakage and diffusion of sour natural gas are the initial state of leakage, leakage aperture, wind speed and hydrogen sulfide volume fraction, etc. Therefore, different hydrogen sulfide volume fraction, wind speed, pipeline operating pressure and pipe diameter are selected as control variables, and three categories of numerical simulation experiments are designed. The main simulation parameters are described in Table 2 below.

[0114] Table 2

[0115]

[0116] 5. Leakage mass flow rate

[0117] The operating pressure of sour natural gas pipelines is generally high. When leakage occurs, there is a large pressure difference between the inside and outside of the pipeline, so that the leakage form can be regarded as a high-speed jet. The jet (JET) model is a model built into the FLACS software specifically for calculating the mass flow rate of high-speed jet leakage. It fully considers the large-aperture (such as complete rupture) leakage of the pipeline for a certain period of time, the emergency shut-off valve is closed, and the pressure difference between the inside and outside of the pipeline changes, and the gas leakage mass flow rate is obtained. Therefore, the present invention uses the JET model to calculate the mass flow rate of sour natural gas pipeline leakage.

[0118] 6. Analysis of simulation results

[0119] (1) Volume fraction of sulfur-containing components (taking hydrogen sulfide as an example)

[0120] See also Figure 4 , Figure 4 This is a cloud diagram of the concentration distribution of sour natural gas under different volume fractions of sulfur-containing components provided in the embodiment of the present application. The figure shows the concentration distribution cloud diagram of sour natural gas under the conditions of 2% and 5% hydrogen sulfide volume fractions. Near the leak, the gas concentration distribution is similar. Due to the heavy gas effect of hydrogen sulfide, it will show sedimentation during the diffusion process, and the higher the volume fraction of hydrogen sulfide, the earlier and more obvious the sedimentation phenomenon will appear.

[0121] As the gas diffusion continues, the higher the hydrogen sulfide volume fraction, the farther the distance at which the hydrogen sulfide volume fraction can reach 0.03% in the downwind direction. Therefore, the potential impact radius of poisoning increases with the increase of hydrogen sulfide volume fraction, and the growth rate is positively correlated with the hydrogen sulfide volume fraction. See Table 3 below, which shows the simulation results of the leakage diffusion of sour natural gas pipelines under the condition of hydrogen sulfide volume fraction of 0.2% to 5%.

[0122] Table 3

[0123]

[0124] Under the same pipeline conditions, the potential impact radius calculated by the second relationship calculation model is 88.5m, which is close to the simulation result when the hydrogen sulfide volume fraction is 1.5%. This shows that under this pipeline condition, when the hydrogen sulfide volume fraction in the sour natural gas is greater than 1.5%, the potential impact radius calculated by the second relationship calculation model will be less accurate. The relationship calculation model after correcting the hydrogen sulfide volume fraction is shown in the following formula (6):

[0125] r=0.0546x 1.5 dp 0.5 (6)

[0126] Among them, r is the radius of the pipeline leakage affected area, x is the volume fraction information of the sulfur-containing component (taking hydrogen sulfide as an example), d is the pipeline outer diameter information (in millimeters, mm), and p is the maximum allowable pressure information of the pipe section (in megapascals, MPa).

[0127] (2) Wind speed

[0128] See also Figure 5 , Figure 5This is a cloud diagram of the concentration distribution of sour natural gas at different times provided in an embodiment of the present application. The figure is a cloud diagram of the concentration distribution of sour natural gas at 1 second (s), 10s, and 20s when a sour natural gas pipeline leaks under a wind speed of 2 meters per second (m / s). Near the leak port, the gas cloud concentration distribution is the highest. This is because the sour natural gas leaks from the high-pressure pipeline at a high speed and carries a large amount of kinetic energy, and the impact of the ambient wind speed has limited effect on it. As the leakage time goes by, the gas cloud moves higher, while the momentum it carries weakens, the speed decreases, and the effect of wind speed on the diffusion of sour natural gas becomes obvious.

[0129] See also Figure 6 , Figure 6 This is a cloud diagram of the concentration distribution of sulfur-containing natural gas under different wind speed conditions provided in the embodiment of the present application. The diagram shows the distribution of the concentration of sulfur-containing natural gas at a certain moment when the sulfur-containing natural gas pipeline leaks under different wind speed conditions. Figure 6 It can be seen that when the wind speed is low, the impact range of sour natural gas poisoning is mainly concentrated in the high altitude; as the wind speed increases, the gas cloud rises to a lower altitude and deflects violently. Ambient wind promotes air circulation, accelerates the diffusion of leaked gas, and dilutes hydrogen sulfide to a certain extent. However, in a short period of time, the range of near-ground hydrogen sulfide volume fraction reaching 0.03% still increases with the increase in wind speed, resulting in an increase in the potential impact radius of poisoning. See Table 4 below for the potential impact radius under different wind speed conditions:

[0130] Table 4

[0131]

[0132] The calculation model of the relationship between the corrected hydrogen sulfide volume fraction and wind speed is shown in the following formula (7):

[0133] r=[0.016ln(u)+0.024]x 1.5 dp 0.5 (7)

[0134] Among them, r is the radius of the pipeline leakage affected area, u is the wind speed information (in meters per second, m / s), x is the volume fraction information of the sulfur-containing component, d is the outer diameter information of the pipeline (in millimeters, mm), and p is the maximum allowable pressure information of the pipe section (in megapascals, MPa).

[0135] (3) Pipeline operating pressure and diameter

[0136] See also Figure 7 , Figure 7This is a potential impact radius comparison diagram under different operating pressures and pipe diameters provided in the embodiment of the present application. The diagram reflects the comparison of simulation results of the potential impact radius of hydrogen sulfide poisoning when the sour natural gas pipeline leaks under different operating pressures and pipe diameters. It can be seen from the figure that when the pipe diameter ranges from 100 to 500 mm and the operating pressure ranges from 2 to 6 MPa, the impact radius of hydrogen sulfide poisoning tends to be between 8.33 m and 584.35 m, and its potential impact radius increases in the same direction as the operating pressure and pipe diameter.

[0137] Under the same pipeline conditions, the potential influence radius calculated by the second relationship calculation model is between 14 and 121.25 m, indicating that when the volume fraction of hydrogen sulfide is 5%, except for some small pipe diameters and pressure conditions, the calculated results of the potential influence radius of other pipeline conditions are significantly smaller than the numerical simulation results.

[0138] The optimization process of the calculation model for the potential impact radius of sour natural gas pipelines is explained below.

[0139] In the actual production process, in order to quickly obtain the potential impact radius of hydrogen sulfide poisoning caused by leakage of sour natural gas pipeline, the second relationship calculation model is used as the basis and the results of numerical simulation under different conditions by FLCAS software are used to optimize it.

[0140] Firstly, the ratio of the simulation results under different hydrogen sulfide volume fractions and wind speed conditions to the calculation results of the second relationship calculation model under the same conditions is used as the correction coefficient, and the curve is fitted to obtain the correction relationship calculation model, such as Figure 8 , Fig. 9 As shown, see Figure 8 and Fig. 9 , Figure 8 is a schematic diagram of a hydrogen sulfide volume fraction correction curve provided in an embodiment of the present application, Fig. 9 is a schematic diagram of a wind speed correction curve provided in an embodiment of the present application, based on Figure 8 and Fig. 9 The correction curve shown adds two parameters, hydrogen sulfide volume fraction and wind speed, into the second relationship calculation model.

[0141] Then, the simulation results of the sour natural gas pipeline under different operating pressures and pipe diameters are compared with the calculation results of the model after adding the two parameters of hydrogen sulfide volume fraction and wind speed under the same conditions, and a series of ratios are obtained as the correction coefficients of the operating pressure and pipe diameter in the model. The correction coefficients of different operating pressures and pipe diameters are shown in Table 5 below:

[0142] Table 5

[0143]

[0144] Finally Figure 8 The corresponding correction relationship calculation model, Fig. 9 The corresponding modified relationship calculation model and coefficients are further reasonably simplified and selected to form the first relationship calculation model suitable for the potential impact radius of hydrogen sulfide poisoning caused by leakage of sour natural gas pipelines.

[0145] The above process simulates and analyzes the poisoning impact range caused by hydrogen sulfide leakage from sour natural gas pipelines under different conditions by FLACS simulation software based on computational fluid dynamics (CFD), determines the potential impact radius, and optimizes the second relationship calculation model according to the simulation results, and uses the correction coefficient to correct the deviation, thereby obtaining a first relationship calculation model with higher accuracy. The potential impact radius of poisoning caused by leakage of sour natural gas pipelines increases with the increase of hydrogen sulfide volume fraction, and the growth rate also increases accordingly; the greater the wind speed, the lower the gas cloud rise height, the more violent the deflection, and the near-ground hydrogen sulfide poisoning impact range increases accordingly, resulting in a positive correlation between the potential impact radius of poisoning and the wind speed. The embodiment of the present application uses a correction coefficient to correct the deviation and simulate this correlation to optimize the second relationship calculation model, and then the optimized first relationship calculation model is used to quickly determine the potential impact radius of hydrogen sulfide poisoning caused by leakage of sour natural gas pipelines in the actual production process, so as to improve the accuracy of determining the potential impact radius.

[0146] 206. The terminal determines the largest radius information between the first radius information and the second radius information as target radius information, where the target radius information is used to indicate the radius of an affected area when a leak occurs in the pipeline to be processed.

[0147] It should be noted that, since the first relationship calculation model only considers the harmful characteristics of poisoning by sulfur-containing components (taking hydrogen sulfide as an example) during the optimization process, the maximum distance of the poisoning impact range is used as the potential impact radius of the sour natural gas pipeline. When the volume fraction of hydrogen sulfide is small, there may be a situation where its calculation result is smaller than that of the second relationship calculation model, resulting in the result of calculating the potential impact radius using the first relationship calculation model becoming conservative. Therefore, in the actual production process, the larger calculation result of the two models under the same conditions can be taken as the potential impact radius of the sour natural gas pipeline.

[0148] In a possible implementation manner, the terminal compares the first radius information and the second radius information, and then determines the largest radius information between the first radius information and the second radius information as the target radius information according to the comparison result.

[0149] It should be noted that the process from step 201 to step 206 is implemented by the processor of the terminal. The solution provided in the embodiment of the present application is simple to operate and requires fewer condition parameters. In the actual production process, the potential impact radius of the sour natural gas pipeline can be quickly determined; it is particularly suitable for calculating the hydrogen sulfide content greater than 20 mg / m3 (mg / m 3 ), that is, the target radius information when the volume fraction of natural gas pipeline leakage is about 0.0013%, that is, the assessment of the potential impact radius.

[0150] The solution provided in the embodiment of the present application provides a first relationship calculation model for determining the radius of the area affected by the leakage of a natural gas pipeline, and then after obtaining the wind speed information of the environment in which the leaking pipeline is located, the volume fraction information of the sulfur-containing component in the natural gas transported in the pipeline, the correction coefficient information of the operating pressure and diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section, the first radius information and the second radius information are determined based on the corresponding information through the first relationship calculation model and the second relationship calculation model respectively, and then the target radius information, that is, the radius of the area affected by the leakage of the natural gas pipeline is determined, without using a Gaussian model to determine the radius information, thereby improving the accuracy of the determined area affected by the leakage of the sour natural gas pipeline.

[0151] All the above optional technical solutions can be arbitrarily combined to form optional embodiments of the present application, which will not be described one by one here.

[0152] It should be noted that the solution provided in the embodiment of the present application can be implemented by a system for determining the area affected by pipeline leakage, see Fig.10 , Fig.10 1 is a schematic diagram of the structure of a system for determining a pipeline leakage impact area provided in an embodiment of the present application. The system includes: a server 1001, a terminal 1002 and a terminal 1003.

[0153] Server 1001 is at least one of a server, multiple servers, a cloud server, a cloud computing platform, and a virtualization center. Optionally, server 1001 communicates with terminal 1002 via wired or wireless communication, and is connected to a wind speed sensor on a pipeline via wired or wireless communication, or is connected to a server of a weather forecast department via wired or wireless communication, and this embodiment of the application is not limited to this. Server 1001 receives information on the volume fraction of sulfur components in the natural gas transported by each pipeline, the operating pressure of each pipeline and the correction coefficient information of the pipe diameter, the pipeline outer diameter information of each pipeline, and the maximum allowable pressure information of the pipe section of each pipeline uploaded by relevant technical personnel through terminal 1002, terminal 1003 or other terminals, and obtains wind speed information of each point on the pipeline from the wind speed sensor on the pipeline or the server of the weather forecast department, and then stores the various information obtained in the above process. Server 1001 is associated with a pipeline information database for storing the information obtained in the above process. The server 1001 is capable of receiving an information acquisition request sent by the terminal 1002, and in response to the received information acquisition request, obtains the wind speed information of the environment in which the pipeline to be processed is located, the volume fraction information of the sulfur-containing component in the natural gas transported by the pipeline to be processed, the correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, the pipeline outer diameter information of the pipeline to be processed and the maximum allowable pressure information of the pipe section of the pipeline to be processed from the pipeline information database, and then sends the obtained wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section to the terminal 1002.

[0154] Terminal 1002 is at least one of a desktop computer, an embedded computer, a computer cluster, etc. Terminal 1002 is a terminal used by relevant technical personnel. Optionally, terminal 1002 communicates with server 1001 and terminal 1003 via wired or wireless communication, which is not limited in the embodiments of the present application. Terminal 1002 also communicates with the concentration sensor on the pipeline via wired or wireless communication. When the concentration sensor detects an abnormal situation in which the concentration near the pipeline exceeds the target threshold, the concentration sensor sends a prompt message to terminal 1002 and sends the location information of the concentration sensor that detects the abnormal situation to terminal 1002. In response to the received prompt message, terminal 1002 sends an information acquisition request to server 1001. The information acquisition request carries the identification of the leaking pipeline and the location information of the leaking point on the pipeline, and receives the wind speed information of the environment in which the pipeline to be processed is located, the volume fraction information of the sulfur-containing component in the natural gas transported by the pipeline to be processed, and the operating pressure and pipe pressure of the pipeline to be processed returned by server 1001. The first radius information is determined based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section to be processed, through a first relationship calculation model, based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the pipeline correction coefficient information, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section; the second radius information is determined based on the second relationship calculation model according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section; based on the first radius information and the second radius information, the target radius information is determined, that is, the potential impact radius of leakage of the pipeline to be processed, that is, the radius of the impact area when the pipeline to be processed leaks, and then the determined target radius information is sent to the terminal 1003.

[0155] Terminal 1003 is at least one of a smart phone, a tablet computer, an e-book reader, a smart speaker, a smart watch, an MP3 (Moving Picture Experts Group Audio Layer III) player, an MP4 (Moving Picture Experts Group Audio Layer IV) player, and a laptop computer. Terminal 1003 is a terminal used by security management personnel. Optionally, terminal 1003 communicates with terminal 1002 via wired or wireless communication, which is not limited in the embodiments of the present application. Terminal 1003 receives the target radius information sent by terminal 1002, and issues an alarm based on the received target alarm information, so that the security management personnel can promptly be informed of the abnormal situation of pipeline leakage, and formulate corresponding response strategies based on the determined target radius information to ensure public safety and property safety.

[0156] Optionally, terminal 1002 and terminal 1003 both refer to one of a plurality of terminals. This embodiment is only illustrated by taking terminal 1002 and terminal 1003 as examples. Those skilled in the art may know that the number of the above terminals may be more or less. For example, the above terminals may be only a few, or the above terminals may be dozens or hundreds, or a greater number. The embodiment of the present application does not limit the number of terminals and device types.

[0157] Fig.11 is a schematic diagram of a device for determining a pipeline leakage impact area provided in an embodiment of the present application, see Fig.11 , the device comprises:

[0158] The acquisition module 1101 is used to acquire wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed;

[0159] The determination module 1102 is used to determine the first radius information based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section through a first relationship calculation model;

[0160] The determination module 1102 is further configured to determine the second radius information according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a second relationship calculation model;

[0161] The determination module 1102 is further used to determine target radius information based on the first radius information and the second radius information, where the target radius information is used to indicate the radius of the area affected when the pipeline to be processed leaks.

[0162] The device provided in the embodiment of the present application provides a first relationship calculation model for determining the radius of the area affected by the leakage of a natural gas pipeline, and then after obtaining the wind speed information of the environment in which the leaking pipeline is located, the volume fraction information of the sulfur-containing component in the natural gas transported in the pipeline, the correction coefficient information of the operating pressure and diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section, the first radius information and the second radius information are determined based on the corresponding information through the first relationship calculation model and the second relationship calculation model respectively, and then the target radius information, that is, the radius of the area affected by the leakage of the natural gas pipeline is determined, without using a Gaussian model to determine the radius information, thereby improving the accuracy of the determined area affected by the leakage of the sour natural gas pipeline.

[0163] In a possible implementation, the first relationship calculation model is:

[0164] r1=[0.016ln(u)+0.024]x 1.5 dp 0.5 δ

[0165] Among them, r1 is the first radius information, u is the wind speed information, x is the volume fraction information of the sulfur-containing component, d is the pipeline outer diameter information, p is the maximum allowable pressure information of the pipe section, and δ is the correction coefficient information of the operating pressure and the pipe diameter.

[0166] In a possible implementation, the second relationship calculation model is:

[0167]

[0168] Among them, r2 is the second radius information, d is the pipeline outer diameter information, and p is the maximum allowable pressure information of the pipe section.

[0169] In a possible implementation, the determination module 1102 is configured to determine the largest radius information between the first radius information and the second radius information as the target radius information.

[0170] In a possible implementation, the acquisition module 1101 is used to send an information acquisition request to a server, where the information acquisition request is used to acquire the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the outer diameter information of the pipeline, and the maximum allowable pressure information of the pipe section;

[0171] Receive the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section returned by the server.

[0172] It should be noted that: the apparatus for determining the pipeline leakage impact area provided in the above embodiment only uses the division of the above functional modules as an example to illustrate when determining the impact area of ​​sour natural gas when a sour natural gas pipeline leaks. In actual applications, the above functions can be assigned to different functional modules as needed, that is, the internal structure of the terminal is divided into different functional modules to complete all or part of the functions described above. In addition, the apparatus for determining the pipeline leakage impact area provided in the above embodiment and the method for determining the pipeline leakage impact area are of the same concept. The specific implementation process is detailed in the method embodiment and will not be repeated here.

[0173] Fig.12It is a structural diagram of a terminal provided in an embodiment of the present application. The terminal 1200 may have relatively large differences due to different configurations or performances, and may include one or more processors (Central Processing Units, CPU) 1201 and one or more memories 1202, wherein the processor 1201 is a very large-scale integrated circuit, which is the computing core and control core of the terminal 1200. Its function is mainly to interpret computer instructions and process data in computer software. At least one program code is stored in the one or more memories 1202, and the at least one program code is loaded and executed by the one or more processors 1201 to implement the methods provided in the above-mentioned various method embodiments. Of course, the terminal 1200 may also have components such as a wired or wireless network interface, a keyboard, and an input and output interface for input and output. The terminal 1200 may also include other components for implementing device functions, which will not be repeated here.

[0174] In an exemplary embodiment, a computer-readable storage medium is also provided, such as a memory including a program code, and the program code can be executed by a processor to complete the method for determining the pipeline leakage impact area in the above embodiment. For example, the computer-readable storage medium can be a read-only memory (ROM), a random access memory (RAM), a compact disc read-only memory (CD-ROM), a magnetic tape, a floppy disk, an optical data storage device, etc.

[0175] In an exemplary embodiment, a computer program product or a computer program is also provided, which includes a computer program code, and the computer program code is stored in a computer-readable storage medium. A processor of a terminal reads the computer program code from the computer-readable storage medium, and the processor executes the computer program code, so that the terminal executes the method steps of the method for determining the pipeline leakage affected area provided in the above embodiment.

[0176] A person skilled in the art will appreciate that all or part of the steps for implementing the above embodiments may be accomplished by hardware or by hardware associated with a program code, and the program may be stored in a computer-readable storage medium, and the above-mentioned storage medium may be a read-only memory, a disk or an optical disk, etc.

[0177] The above are only optional embodiments of the present application and are not intended to limit the present application. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the present application should be included in the protection scope of the present application.

Claims

1. A method for determining a pipeline leakage impact area, characterized in that: The method comprises: Obtaining wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed; Determine the first radius information through a first relationship calculation model based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section; Determine the second radius information according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a second relationship calculation model; Based on the first radius information and the second radius information, determine target radius information, where the target radius information is used to indicate the radius of an affected area when a leak occurs in the pipeline to be processed; Wherein, the first relationship calculation model is: in, is the first radius information, is the wind speed information, is the volume fraction information of the sulfur-containing component, is the outer diameter information of the pipeline, is the maximum allowable pressure information of the pipe section, is the correction coefficient information of the operating pressure and pipe diameter; The second relationship calculation model is: in, is the second radius information, is the outer diameter information of the pipeline, It is the maximum allowable pressure information of the pipe section.

2. The method for determining the pipeline leakage impact area according to claim 1, characterized in that: The determining target radius information based on the first radius information and the second radius information includes: The largest radius information between the first radius information and the second radius information is determined as the target radius information.

3. The method for determining the pipeline leakage impact area according to claim 1, characterized in that: The process of obtaining wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed includes: Sending an information acquisition request to a server, wherein the information acquisition request is used to obtain the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section; Receive the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section returned by the server.

4. A device for determining a pipeline leakage impact area, characterized in that: The device comprises: An acquisition module is used to acquire wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipeline section of the pipeline to be processed; A determination module, configured to determine the first radius information based on the wind speed information, the volume fraction information of the sulfur-containing component, the operating pressure and the correction coefficient information of the pipeline, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a first relationship calculation model; The determination module is further used to determine the second radius information according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a second relationship calculation model; The determination module is further used to determine target radius information based on the first radius information and the second radius information, wherein the target radius information is used to indicate the radius of an affected area when a leak occurs in the pipeline to be processed; Wherein, the first relationship calculation model is: in, is the first radius information, is the wind speed information, is the volume fraction information of the sulfur-containing component, is the outer diameter information of the pipeline, is the maximum allowable pressure information of the pipe section, is the correction coefficient information of the operating pressure and pipe diameter; The second relationship calculation model is: in, is the second radius information, is the outer diameter information of the pipeline, It is the maximum allowable pressure information of the pipe section.

5. A system for determining the area affected by pipeline leakage, characterized in that: The system comprises: The server is used to obtain wind speed information of the environment in which the pipeline to be processed is located, volume fraction information of sulfur-containing components in the natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pressure information of the pipe section of the pipeline to be processed; and send the wind speed information, volume fraction information of sulfur-containing components, correction coefficient information of the operating pressure and pipe diameter, pipeline outer diameter information, and maximum allowable pressure information of the pipe section to the terminal; The terminal is used to receive the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section; determine the first radius information based on the wind speed information, the volume fraction information of the sulfur-containing component, the correction coefficient information of the operating pressure and the pipe, the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a first relationship calculation model; determine the second radius information according to the pipeline outer diameter information and the maximum allowable pressure information of the pipe section through a second relationship calculation model; determine the target radius information based on the first radius information and the second radius information, and the target radius information is used to indicate the radius of the affected area when the pipeline to be treated leaks; The terminal is further used to issue an alarm based on the target radius information; Wherein, the first relationship calculation model is: in, is the first radius information, is the wind speed information, is the volume fraction information of the sulfur-containing component, is the outer diameter information of the pipeline, is the maximum allowable pressure information of the pipe section, is the correction coefficient information of the operating pressure and pipe diameter; The second relationship calculation model is: in, is the second radius information, is the outer diameter information of the pipeline, It is the maximum allowable pressure information of the pipe section.

6. A terminal, characterized in that: The terminal includes one or more processors and one or more memories, wherein at least one program code is stored in the one or more memories, and the program code is loaded and executed by the one or more processors to implement the operations performed by the method for determining the pipeline leakage impact area according to any one of claims 1 to 3.

7. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores at least one program code, and the program code is loaded and executed by a processor to implement the operations performed by the method for determining the pipeline leakage impact area according to any one of claims 1 to 3.

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