CN114491877A

CN114491877A - Method, device, system, terminal and medium for determining pipeline leakage influence area

Info

Publication number: CN114491877A
Application number: CN202011259753.6A
Authority: CN
Inventors: 何军; 朱愚; 宋伟; 沈大均; 谭红; 张艳玲; 左应祥; 张雪莹; 颜硕; 廉琪; 张瑛茵
Original assignee: Petrochina Co Ltd
Current assignee: Petrochina Co Ltd
Priority date: 2020-11-12
Filing date: 2020-11-12
Publication date: 2022-05-13

Abstract

The application provides a method, a device, a system, a terminal and a medium for determining a pipeline leakage influence area, and belongs to the technical field of natural gas pipe network safety and measurement. The application provides a first relation calculation model for determining the radius of a natural gas pipeline leakage influence area, and further obtains the wind speed information of the environment where the leaked pipeline is located, the volume fraction information of sulfur-containing components in natural gas transported in the pipeline, the correction coefficient information of the running pressure and the pipe diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of the pipe section of the pipeline, and respectively determines the first radius information and the second radius information based on corresponding information, so that target radius information is realized, namely the radius of the natural gas pipeline leakage influence area is determined, the radius information is determined without using a Gaussian model, and therefore the accuracy of the determined sulfur-containing natural gas pipeline leakage influence area is improved.

Description

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

Technical Field

The application relates to the technical field of natural gas pipe network safety and measurement, in particular to a method, a device, a system, a terminal and a medium for determining a pipeline leakage influence area.

Background

Natural gas is used more and more widely in industrial production and in residential life as a clean energy source. Since natural gas produced from a production site typically contains elemental sulfur (typically in the form of hydrogen sulfide), prior to use, the sour gas is transported via natural gas pipelines to a processing plant for processing to obtain a safe-to-use natural gas. In the process of transmission, once leakage occurs in a sulfur-containing natural gas pipeline, serious poisoning accidents are caused. Therefore, in the actual operation process of the sulfur-containing natural gas pipeline, the potential influence radius of the hydrogen sulfide poisoning is reasonably determined, and the influence range is determined, so that the method has great significance for ensuring the safe operation of the sulfur-containing natural gas pipeline.

At present, when radius information of a potential influence area of sulfur-containing natural gas pipeline leakage is determined, a Gaussian model is mainly used for determining superposition of volume fractions of sulfur-containing natural gas plumes and plumes at different moments so as to represent the radius information of the potential influence area of hydrogen sulfide poisoning caused by sulfur-containing natural gas pipeline leakage.

In the implementation process, a Gaussian model is generally used for diffusion analysis of neutral gas, but hydrogen sulfide belongs to heavy gas, and the accuracy of the potential influence area of hydrogen sulfide poisoning determined by using the method is low.

Disclosure of Invention

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

in one aspect, a method for determining an area affected by a pipeline leakage is provided, the method comprising:

acquiring wind speed information of an environment where a pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of 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 a pipe section of the pipeline to be processed;

determining first radius information based on the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a first relation calculation model;

determining second radius information according to the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a second relation calculation model;

and determining target radius information based on the first radius information and the second radius information, wherein the target radius information is used for indicating the radius of an area affected when the pipeline to be processed leaks.

In one possible implementation, the first relational computation model is:

r₁＝[0.016ln(u)+0.024]x^1.5dp^0.5δ

wherein r is₁Is the first radius information, u is the wind speed information, x is the volume fraction information of the sulfur-containing component, d is the outside of the pipelineAnd d, correcting the pipe diameter according to the correction coefficient information, wherein the p is the maximum allowable pressure information of the pipe section, and the delta is the correction coefficient information of the operating pressure and the pipe diameter.

In one possible implementation, the second relational computation model is:

wherein r is₂And d is the information of the outer diameter of the pipeline, and p is the information of the maximum allowable pressure of the pipeline section.

In one possible implementation, the determining target radius information based on the first radius information and the second radius information includes:

and determining the largest radius information in the first radius information and the second radius information as the target radius information.

In a possible implementation manner, the acquiring of the wind speed information of the environment where 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 the 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 includes:

sending an information acquisition request to a server, wherein the information acquisition request is used for acquiring the wind speed information, the volume fraction information of the sulfur-containing components, 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 pipeline section;

and receiving the wind speed information, the volume fraction information of the sulfur-containing components, 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 pipeline section, which are returned by the server.

In one aspect, there is provided an apparatus for determining an area of influence of a leakage in a pipe, the apparatus comprising:

the system comprises an acquisition module, a control module and a processing module, wherein the acquisition module is used for acquiring wind speed information of the environment where a pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and the pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed and maximum allowable pressure information of a pipe section of the pipeline to be processed;

the determining module is used for determining first radius information based on the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a first relation calculation model;

the determining module is further used for determining second radius information according to the pipeline outer diameter information and the pipeline section maximum allowable pressure information through a second relation calculation model;

the determining module is further configured 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 a radius of an area affected by the pipe to be processed when a leak occurs.

In one possible implementation, the first relational computation model is:

r₁＝[0.016ln(u)+0.024]x^1.5dp^0.5δ

wherein r is₁The first radius information is u, the wind speed information is u, the volume fraction information of the sulfur-containing component is x, the outer diameter information of the pipeline is d, the maximum allowable pressure information of the pipeline section is p, and the correction coefficient information of the operating pressure and the pipe diameter is delta.

In one possible implementation, the second relational computation model is:

In a possible implementation manner, the determining module is configured to determine the largest radius information of the first radius information and the second radius information as the target radius information.

In a possible implementation manner, the obtaining module is configured to send an information obtaining request to a server, where the information obtaining 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 pipe outer diameter information, and the maximum allowable pressure information of the pipe section;

In one aspect, a system for determining an area of influence of a pipeline leak is provided, the system comprising:

the server is used for acquiring wind speed information of the environment where the pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of 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 a pipe section of the pipeline to be processed; sending the wind speed information, the volume fraction information of the sulfur-containing components, 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 pipeline section to a terminal;

the terminal is used for receiving the wind speed information, the volume fraction information of the sulfur-containing components, 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 pipeline section; determining first radius information based on the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a first relation calculation model; determining second radius information according to the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a second relation calculation model; determining target radius information based on the first radius information and the second radius information, wherein the target radius information is used for indicating the radius of an affected area when the pipeline to be processed leaks;

the terminal is also used for alarming based on the target radius information.

In one aspect, a terminal is provided that includes one or more processors and one or more memories having at least one program code stored therein, the program code being loaded and executed by the one or more processors to perform operations performed by the method for determining a pipe leak impact region.

In one aspect, a computer-readable storage medium having at least one program code stored therein is provided, the program code being loaded into and executed by a processor to implement the operations performed by the method for determining a pipe leakage impact area.

In an aspect, a computer program product or a computer program is provided, the computer program product or the computer program comprising computer program code, the computer program code being stored in a computer readable storage medium. The processor of the terminal reads the computer program code from the computer-readable storage medium, and the processor executes the computer program code to perform the operations performed by the method for determining a pipe leakage impact area.

According to the scheme, the radius of the natural gas pipeline leakage influence area is determined by providing a first relation calculation model, and then after the wind speed information of the environment where the leaked pipeline is located is acquired, the volume fraction information of sulfur-containing components in natural gas transported in the pipeline, the correction coefficient information of the running pressure and the pipe diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of a pipe section of the pipeline are acquired, the first relation calculation model and the second relation calculation model are respectively used for determining the first radius information and the second radius information based on corresponding information, and further target radius information is achieved, namely the radius of the natural gas pipeline leakage influence area is determined, the radius information does not need to be determined by using a Gaussian model, and therefore the accuracy of the determined sulfur-containing natural gas pipeline leakage influence area is improved.

Drawings

In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present application, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.

Fig. 1 is a flowchart of a method for determining an area affected by a pipeline leakage according to an embodiment of the present application;

FIG. 2 is a flowchart of a method for determining an area affected by a pipeline leakage according to an embodiment of the present disclosure;

FIG. 3 is a two-dimensional schematic diagram of a physical model of a pipeline leakage provided by an embodiment of the present application;

FIG. 4 is a cloud diagram of the sulfur-containing natural gas concentration distribution at different volume fractions of sulfur-containing components according to an embodiment of the present application;

FIG. 5 is a cloud graph of the sulfur-containing natural gas concentration distribution at different times according to an embodiment of the present disclosure;

FIG. 6 is a cloud of sulfur-containing natural gas concentration profiles at different wind speeds according to an embodiment of the present disclosure;

FIG. 7 is a graph comparing the potential radius of influence for different operating pressures versus pipe diameters as provided by the examples of the present application;

FIG. 8 is a schematic illustration of a hydrogen sulfide volume fraction correction curve provided in an embodiment of the present application;

FIG. 9 is a schematic view of a wind speed correction curve provided by an embodiment of the present application;

FIG. 10 is a schematic structural diagram of a system for determining an area affected by a pipeline leakage according to an embodiment of the present application;

FIG. 11 is a schematic structural diagram of an apparatus for determining an area affected by a pipeline leakage according to an embodiment of the present application;

fig. 12 is a schematic structural diagram of a terminal according to an embodiment of the present application.

Detailed Description

To make the objects, technical solutions and advantages of the present application more clear, embodiments of the present application will be described in further detail below with reference to the accompanying drawings.

The embodiment of the application provides a method for determining a pipeline leakage influence area in the technical field of natural gas pipeline network safety and measurement, and the method is particularly used for evaluating potential influence of sulfur-containing natural gas pipeline leakage poisoning. Related technicians upload volume fraction information of sulfur-containing components in natural gas transported by each pipeline, correction coefficient information of operating pressure and pipe diameter of each pipeline, pipeline outer diameter information of each pipeline and maximum allowable pressure information of pipe sections of each pipeline to a server, so that the terminal obtains volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and the pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed and maximum allowable pressure information of a pipe section of the pipeline to be processed from the server, and obtains the wind speed information of the environment where the pipeline to be processed is located, which is obtained by the server from a wind speed sensor near the leakage point or a server of a weather forecast department, and then determining an influence area when the pipeline to be processed leaks based on the acquired information.

Fig. 1 is a flowchart of a method for determining an area affected by a pipeline leakage according to an embodiment of the present application, and referring to fig. 1, the method includes:

101. the method comprises the steps that a terminal obtains wind speed information of the environment where a pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of 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 a pipe section of the pipeline to be processed.

102. And the terminal determines first radius information based on the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a first relation calculation model.

103. And the terminal determines second radius information according to the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a second relation calculation model.

104. And the terminal determines target radius information based on the first radius information and the second radius information, wherein the target radius information is used for indicating the radius of an affected area when the pipeline to be processed leaks.

The scheme provided by the embodiment of the application comprises the steps of providing a first relation calculation model for determining the radius of the natural gas pipeline leakage influence area, further, after acquiring the wind speed information of the environment where the pipeline which is leaked is positioned, the volume fraction information of sulfur-containing components in the natural gas transported in the pipeline, the correction coefficient information of the running pressure and the pipe diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of a pipe section of the pipeline, determining first radius information and second radius information based on the corresponding information through a first relation calculation model and a second relation calculation model respectively, and further, target radius information, namely the radius of the natural gas pipeline leakage influence area is determined, and the radius information is determined without using a Gaussian model, so that the accuracy of the determined sulfur-containing natural gas pipeline leakage influence area is improved.

In one possible implementation, the first relational computation model is:

r₁＝[0.016ln(u)+0.024]x^1.5dp^0.5δ

In one possible implementation, the second relational computation model is:

Fig. 2 is a flowchart of a method for determining an area affected by a pipeline leakage according to an embodiment of the present application, and referring to fig. 2, the method includes:

201. the terminal sends an information acquisition request to the server, wherein the information acquisition request is used for acquiring wind speed information of the environment where the pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of 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 a pipe section of the pipeline to be processed.

It should be noted that, the terminal detects the leakage condition of each pipeline in real time, determines the pipeline with leakage as the pipeline to be processed when detecting that any pipeline has leakage, and obtains the position information of the leakage point with leakage on the pipeline, and sends an information obtaining request to the server based on the identifier of the pipeline to be processed and the position information of the leakage point, where the information obtaining request carries the identifier of the pipeline to be processed and the position information of the leakage point.

The main sulfur-containing component in the sulfur-containing natural gas is hydrogen sulfide, and optionally, the sulfur-containing natural gas further includes other sulfur-containing components, which is not limited in the embodiment of the present application.

202. And the server sends the acquired wind speed information, the volume fraction information of the sulfur-containing components, 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 pipeline section to the terminal.

It should be noted that the server is associated with a pipeline information database, and is used for storing volume fraction information of sulfur-containing components in the natural gas transported by each pipeline, correction coefficient information of operating pressure and pipe diameter of each pipeline, pipeline outer diameter information of each pipeline, and maximum allowable pressure information of pipe sections of each pipeline, which are uploaded by related technicians, based on the identification of each pipeline. The server is further connected to each wind speed sensor on The pipeline through a wired network or a wireless network, such as The 4Generation Mobile Communication Technology (4G network), etc., or connected to a server of a weather forecast department through a wired network or a wireless network, so as to acquire wind speed information of The environment in each location on The pipeline.

In a possible implementation manner, in response to a received information acquisition request, according to an identifier of a pipeline to be processed carried by the information acquisition request and position information of a leakage point on the pipeline to be processed, a server acquires wind speed information of an environment where the leakage point on the pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and maximum allowable pipe section pressure information corresponding to the leakage point on the pipeline to be processed, and further sends each acquired information to a terminal.

Wherein, the correction coefficient information of the operating pressure and the pipe diameter corresponding to different operating pressures and different pipe diameters is shown in the following table 1:

TABLE 1

203. And the terminal receives the wind speed information, the volume fraction information of the sulfur-containing components, 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 pipeline section, which are returned by the server.

204. And the terminal determines first radius information based on the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a first relation calculation model.

In a possible implementation manner, the terminal inputs the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section into a first relation calculation model, and outputs the first radius information.

It should be noted that, the first relational computation model is referred to the following formula (1):

r₁＝[0.016ln(u)+0.024]x^1.5dp^0.5δ (1)

wherein r is₁The first radius information (unit is meter, m), the wind speed information (unit is meter/second, m/s), the volume fraction information of the sulfur-containing component, the pipe outer diameter information (unit is millimeter, mm), the maximum allowable pressure information (unit is megapascal, MPa) of the pipe section, and the correction coefficient information of the operating pressure and the pipe diameter.

It should be noted that the first relational computation model is obtained by performing optimization based on the second relational computation model, and the process of obtaining the first relational computation model is referred to step 205, which is not described herein again.

205. And the terminal determines second radius information according to the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a second relation calculation model.

In one possible implementation, the terminal inputs the pipe outer diameter information and the maximum allowable pressure information of the pipe section into a second relation calculation model, and outputs the second radius information.

It should be noted that, the second relational computation model is referred to the following formula (2):

wherein r is₂Is the second radius information (in meters, m), d is the pipe outside diameter information (in millimeters, mm), and p is the pipe section maximum allowable pressure information (in megapascals, MPa).

It should be noted that the second relational computation model is obtained by performing simulation analysis on a potential influence range of poisoning of sulfur-containing components (taking hydrogen sulfide as an example) caused by leakage of the sulfur-containing natural gas pipeline under different conditions by using fire explosion (FLACS) numerical simulation software. When FLACS software is used for simulation analysis, the method is mainly completed through the steps of front computer aided design (CASD) modeling, grid division, simulation parameter setting, model solving, post Flow (FLOWVIS) result processing and the like, and various steps and related contents are introduced as follows:

mathematical model

After sulfur-containing natural gas leaks, the sulfur-containing natural gas diffuses in the air and belongs to unsteady turbulent motion, so a Reynolds-average quasi-compression (N-S) relation calculation model is selected as a main control relation calculation model, wherein the related relation calculation model comprises a mass conservation equation, a momentum conservation equation and an energy conservation equation, and the mass conservation equation, the momentum conservation equation and the energy conservation equation are respectively referred to the following formulas (3) to (5):

wherein rho is density (unit is kilogram/cubic meter, kg/m)³) T is time (in units of seconds, S), u is velocity (in units of meters per second, m/S), S_mAs well as any custom quality sources, between the continuous and discrete phases.

Where t is time (in seconds, s) and ρ is density (in kilograms/cubic meter, kg/m)³) U is the velocity (m/s ), p is the static pressure (Pa, Pa), τ is the stress tensor, g is the gravitational force, and F is the external force.

Wherein rho is density (unit is kilogram/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) degrees Celsius)²·℃))，c_pIs specific heat capacity (unit is kilojoule/kilogram-degree centigrade, kJ/(kg-degree centigrade)), S_TIs a viscous term.

(2) Physical model and boundary conditions

The method takes sulfur-containing natural gas pipeline fracture (full-pipe-diameter leakage) as a leakage simulation scene, and considers the condition that an emergency stop valve is closed after the sulfur-containing natural gas pipeline leaks for 30 s. The mixture continues to diffuse, with the farthest distance that the downwind hydrogen sulfide volume fraction can reach 0.03% being the radius of potential poisoning effect.

The calculation areas in the three directions of the x axis, the y axis and the z axis are respectively 0-200 m, 0-1000 m and 0-500 m, and the coordinate of the leakage point is (100, 50 and 0.3). Setting the wind direction in the positive direction of the y axis, the atmospheric stability as D and the temperature as 20 ℃ in the boundary conditions, considering the leakage situation in the vertical and horizontal directions, referring to fig. 3 for a two-dimensional schematic diagram of a physical model of a leakage scene, and fig. 3 is a two-dimensional schematic diagram of a physical model of pipeline leakage provided by the embodiment of the application.

Three, grid division

In order to reduce the calculation amount and accelerate the solving speed of the relational computation model while ensuring the accuracy, the grid size near the leakage port is encrypted to be 1.5 m/grid in each coordinate axis direction, other areas are extended by a stretching (Stretch) command, and finally the total number of the grids is 54120.

Fourthly, simulating parameter conditions

The main factors influencing the leakage and diffusion of the sulfur-containing natural gas include the initial leakage state, the leakage aperture, the wind speed, the volume fraction of hydrogen sulfide and the like. Therefore, three categories of numerical simulation experiments are designed by selecting different conditions such as volume fraction of hydrogen sulfide, wind speed, pipeline operation pressure, pipe diameter and the like as control variables, and the description of main simulation parameters refers to the following table 2.

TABLE 2

Fifth, leakage mass flow rate

The sulfur-containing natural gas pipeline has higher operating pressure generally, and when leakage occurs, a larger pressure difference exists between the inside and the outside of the pipeline, so that the leakage form can be regarded as high-speed injection. A JET flow (JET) model is a built-in model special for calculating mass flow rate in a high-speed JET leakage form in FLACS software, and obtains gas leakage mass flow rate under the conditions that an emergency cut-off valve is closed when a pipeline large-aperture (such as complete rupture) leakage is fully considered for a certain time and the pressure difference between the inside and the outside of the pipeline is changed. Therefore, the present invention utilizes a JET model to calculate the mass flow rate of sour natural gas pipeline leaks.

Sixthly, analysis of simulation result

(1) Volume fraction of sulfur-containing component (in the case of hydrogen sulfide)

Referring to fig. 4, fig. 4 is a concentration distribution cloud chart of the sour natural gas at different volume fractions of the sour component according to the example of the present application, which shows the concentration distribution cloud chart of the sour natural gas at 2% and 5% of the hydrogen sulfide volume fraction. The gas concentration profile is similar near the leak. Due to the heavy gas effect of the hydrogen sulfide, the hydrogen sulfide can show a sedimentation phenomenon in the diffusion process, and the higher the volume fraction of the hydrogen sulfide is, the earlier and more obvious the sedimentation phenomenon can appear.

The higher the volume fraction of hydrogen sulfide, the longer the distance that the volume fraction of hydrogen sulfide can reach 0.03% downwind is, and the larger the volume fraction of hydrogen sulfide, so the radius of potential poisoning effect increases with the increase of the volume fraction of hydrogen sulfide, and the increase range is positively correlated with the volume fraction of hydrogen sulfide. Referring to table 3 below, table 3 shows the results of simulating the leakage diffusion of the sulfur-containing natural gas pipeline under the condition that the volume fraction of hydrogen sulfide is 0.2% -5%.

TABLE 3

Under the same pipeline condition, the potential influence radius calculated by using the second relation calculation model is 88.5m, which is similar to the simulation result when the volume fraction of the hydrogen sulfide is 1.5%. It is shown that under the pipeline condition, when the volume fraction of hydrogen sulfide in the sulfur-containing natural gas is more than 1.5%, the accuracy of the potential influence radius calculated by the model second relation calculation model is poor. The relational calculation model after correcting the volume fraction of hydrogen sulfide is shown in the following formula (6):

r＝0.0546x^1.5dp^0.5 (6)

wherein r is the radius of the pipeline leakage influence area, x is volume fraction information of sulfur-containing components (taking hydrogen sulfide as an example), d is pipeline outer diameter information (in millimeter and mm), and p is pipeline section maximum allowable pressure information (in megapascals and MPa).

(2) Wind speed

Referring to fig. 5, fig. 5 is a cloud chart of the distribution of the sulfur-containing natural gas concentration at different times, which is a cloud chart of the distribution of the sulfur-containing natural gas concentration at times 1 second(s), 10s, and 20s when a sulfur-containing natural gas pipeline leaks at a wind speed of 2 meters per second (m/s). The gas cloud concentration distribution is highest near the leakage port, because the sulfur-containing natural gas has higher speed after leaking from the high-pressure pipeline and carries a large amount of kinetic energy, and the impact of the environmental wind speed has limited influence on the sulfur-containing natural gas. Along with the lapse of leakage time, the gas cloud motion height increases, and carries momentum and weakens, and speed diminishes, and the wind speed becomes obvious to the influence effect that contains sulphur natural gas diffusion.

Referring to fig. 6, fig. 6 is a cloud chart of the distribution of the sulfur-containing natural gas concentration under different wind speed conditions according to the embodiment of the present application, which shows the distribution of the sulfur-containing natural gas concentration at a certain time when the sulfur-containing natural gas pipeline leaks under different wind speed conditions. As can be seen from fig. 6, when the wind speed is small, the poisoning effect range of the sulfur-containing natural gas is mainly gathered at high altitude; as the wind speed increases, the rising height of the air cloud decreases while a sharp deflection occurs. The ambient wind promotes the circulation of air, accelerates the diffusion of leaked gas, and plays a role in diluting hydrogen sulfide to a certain extent. However, in a short time, the near-surface hydrogen sulfide volume fraction of 0.03 percent still increases with the increase of wind speed, so that the potential influence radius of poisoning also increases. The radius of potential impact under different wind speed conditions is seen in table 4 below:

TABLE 4

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

r＝[0.016ln(u)+0.024]x^1.5dp^0.5 (7)

wherein r is the radius of the pipeline leakage influence area, u is the wind speed information (in meters per second, m/s), x is the volume fraction information of the sulfur-containing components, d is the pipeline outer diameter information (in millimeters, mm), and p is the maximum allowable pressure information (in megapascals, MPa) of the pipeline section.

(3) Operating pressure and pipe diameter of pipeline

Referring to fig. 7, fig. 7 is a graph comparing the radius of potential influence under different operating pressure and pipe diameter conditions, which reflects the comparison of the simulation results of radius of potential influence of hydrogen sulfide poisoning due to leakage of the sulfur-containing natural gas pipeline under different operating pressure and pipe diameter conditions. As can be seen from the figure, when the pipe diameter ranges from 100 mm to 500mm and the operating pressure ranges from 2 MPa to 6MPa, the radius of influence of hydrogen sulfide poisoning tends to range from 8.33m to 584.35m, and the potential radius of influence increases along with the same direction of the operating pressure and the pipe diameter.

Under the same pipeline condition, the potential influence radius calculated by adopting the second relation calculation model is 14-121.25 m, which shows that when the volume fraction of the hydrogen sulfide is 5%, the calculation results of the potential influence radii of other pipeline conditions are obviously smaller than the numerical simulation results except the individual small pipe diameter and pressure conditions.

The optimization process of the potential influence radius calculation model of the sulfur-containing natural gas pipeline is explained below.

In the actual production process, in order to quickly obtain the potential influence radius of the sulfur-containing natural gas pipeline leakage hydrogen sulfide poisoning, the numerical simulation results of the FLCAS software under different conditions are used for optimizing the radius on the basis of the second relation calculation model.

Firstly, taking the ratio of the simulation results of different hydrogen sulfide volume fractions and wind speed conditions to the calculation results of the second relation calculation model under the same conditions as a correction coefficient, and fitting a curve to obtain the correction relation calculation model, as shown in fig. 8 and 9, see fig. 8 and 9, wherein fig. 8 is a schematic diagram of a hydrogen sulfide volume fraction correction curve provided by the embodiment of the application, and fig. 9 is a schematic diagram of a wind speed correction curve provided by the embodiment of the application, and two parameters of hydrogen sulfide volume fraction and wind speed are added into the second relation calculation model based on the correction curves shown in fig. 8 and 9.

Then, comparing simulation results of the sulfur-containing natural gas pipeline under different operating pressures and pipe diameters with calculation results of a model added with two parameters of hydrogen sulfide volume fraction and wind speed under the same condition, obtaining a series of ratios as correction coefficients of the operating pressure and the pipe diameter in the model, wherein the correction coefficients of the different operating pressures and the pipe diameters are shown in the following table 5:

TABLE 5

And finally, further reasonably simplifying and accepting the correction relation calculation model corresponding to the graph 8, the correction relation calculation model corresponding to the graph 9 and the coefficient to form a first relation calculation model suitable for the radius of potential influence of the sulfur-containing natural gas pipeline leakage hydrogen sulfide poisoning.

In the process, through FLACS simulation software based on Computational Fluid Dynamics (CFD), the poisoning influence range caused by hydrogen sulfide leakage of the sulfur-containing natural gas pipeline under different conditions is simulated and analyzed, the potential influence radius is determined, the second relation calculation model is optimized according to the simulation result, and the deviation is corrected by adopting the correction coefficient, so that the first relation calculation model with higher accuracy is obtained. The radius of potential influence of sulfur-containing natural gas pipeline leakage poisoning is increased along with the increase of the volume fraction of hydrogen sulfide, and the increase amplitude is increased; the larger the wind speed is, the rising height of the gas cloud is reduced, the deflection becomes severe, the influence range of the near-ground hydrogen sulfide poisoning is enlarged, and the poisoning potential influence radius is in positive correlation with the wind speed.

206. And the terminal determines the maximum radius information in the first radius information and the second radius information as target radius information, wherein the target radius information is used for indicating the radius of an affected area when the pipeline to be processed leaks.

It should be noted that, since only the hazardous characteristic of poisoning of the sulfur-containing component (taking hydrogen sulfide as an example) is considered in the optimization process by the first relational computation model, the maximum distance of the toxic influence range is taken as the potential influence radius of the sulfur-containing natural gas pipeline. When the volume fraction of hydrogen sulfide is small, there may be a case where the calculation result thereof is smaller than that of the second relational computation model, resulting in that the result of calculating the potentially influencing radius using the first relational computation model becomes conservative. Therefore, in the actual production process, the larger calculation results of the two models under the same conditions can be taken as the potential influence radius of the sulfur-containing natural gas pipeline.

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

It should be noted that the processes of step 201 to step 206 are implemented by a processor of the terminal. The scheme provided by the embodiment of the application is simple to operate, the required condition parameters are less, and the potential influence radius of the sulfur-containing natural gas pipeline can be quickly determined in the actual production process; is particularly suitable for calculating the hydrogen sulfide content of more than 20 milligrams per cubic meter (mg/m)³) Namely, the target radius information when the natural gas pipeline with the volume fraction of about 0.0013% leaks, namely, the evaluation of the potential influence radius.

All the above optional technical solutions may be combined arbitrarily to form optional embodiments of the present application, and are not described herein again.

It should be noted that the solution provided in the embodiment of the present application can be implemented by a system for determining an area affected by a pipeline leakage, see fig. 10, where fig. 10 is a schematic structural diagram of a system for determining an area affected by a pipeline leakage provided in the embodiment of the present application, and the system includes: server 1001, terminal 1002, and terminal 1003.

The server 1001 is at least one of a server, a plurality of servers, a cloud server, a cloud computing platform, and a virtualization center. Optionally, the server 1001 communicates with the terminal 1002 through a wired or wireless communication manner, and is connected to the wind speed sensor on the pipeline through a wired or wireless communication manner, or is connected to a server of a weather forecasting department through a wired or wireless communication manner, which is not limited in the embodiment of the present application. The server 1001 receives volume fraction information of sulfur-containing components in natural gas transported by each pipeline, correction coefficient information of operating pressure and pipe diameter of each pipeline, pipeline outer diameter information of each pipeline, and maximum allowable pressure information of pipe sections of each pipeline, which are uploaded by a relevant technician through the terminal 1002, the terminal 1003 or other terminals, acquires wind speed information of points on the pipeline from a wind speed sensor on the pipeline or a server of a weather forecast department, and further stores various information acquired in the above process. The server 1001 is associated with a pipe information database for storing information acquired by the above process. The server 1001 can receive an information acquisition request sent by the terminal 1002, and in response to the received information acquisition request, acquire wind speed information of an environment where a pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of operating pressure and pipe diameter of the pipeline to be processed, pipeline outer diameter information of the pipeline to be processed, and pipe section maximum allowable pressure information of the pipeline to be processed from a pipeline information database, and further send the acquired wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipe diameter, the pipeline outer diameter information, and the pipe section maximum allowable pressure information to the terminal 1002.

The terminal 1002 is at least one of a desktop computer, an embedded computer, a cluster of computers, and the like. The terminal 1002 is a terminal used by the relevant technician. Optionally, the terminal 1002 communicates with the server 1001 and the terminal 1003 in a wired or wireless communication manner, which is not limited in this embodiment of the present application. The terminal 1002 also communicates with a concentration sensor on the pipeline by a wired or wireless communication mode, when the concentration sensor detects an abnormal condition that the concentration near the pipeline exceeds a target threshold value, the concentration sensor sends prompt information to the terminal 1002 and sends position information of the concentration sensor detecting the abnormal condition to the terminal 1002, the terminal 1002 responds to the received prompt information, sends an information acquisition request to the server 1001, the information acquisition request carries an identification of the pipeline with leakage and position information of a leakage point on the pipeline with leakage, and receives wind speed information of the environment where the pipeline to be processed 1001 is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of the operating pressure and the pipe diameter of the pipeline to be processed, outer diameter information of the pipeline to be processed and maximum allowable pressure information of a pipe section of the pipeline to be processed, which are returned by the server, determining first radius information based on the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a first relation calculation model; determining second radius information according to the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a second relation calculation model; based on the first radius information and the second radius information, target radius information, that is, a potential influence radius of the to-be-processed pipeline, that is, a radius of an influence area when the to-be-processed pipeline leaks, is determined, and then the determined target radius information is sent to the terminal 1003.

The terminal 1003 is at least one of a smart phone, a tablet pc, an e-book reader, a smart speaker, a smart watch, an MP3(Moving Picture Experts Group Audio Layer III, motion Picture Experts compression standard Audio Layer 3) player, an MP4(Moving Picture Experts Group Audio Layer IV, motion Picture Experts compression standard Audio Layer 4) player, and a laptop. The terminal 1003 is a terminal used by a security manager. Optionally, the terminal 1003 communicates with the terminal 1002 through a wired or wireless communication method, which is not limited in this embodiment of the present application. The terminal 1003 receives the target radius information sent by the terminal 1002, and gives an alarm based on the received target alarm information, so that a safety manager can timely know the abnormal condition of pipeline leakage, and a corresponding response strategy is formulated based on the determined target radius information, thereby ensuring public safety and property safety.

Alternatively, the terminal 1002 and the terminal 1003 each refer to one of a plurality of terminals, and the present embodiment is illustrated by the terminal 1002 and the terminal 1003 only. Those skilled in the art will appreciate that the number of terminals described above may be greater or fewer. For example, the number of the terminals may be only a few, or the number of the terminals may be several tens or hundreds, or more, and the number of the terminals and the type of the device are not limited in the embodiment of the present application.

Fig. 11 is a schematic structural diagram of an apparatus for determining an area affected by a pipeline leakage according to an embodiment of the present application, and referring to fig. 11, the apparatus includes:

an obtaining module 1101, configured to obtain wind speed information of an environment where a pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of 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 a pipe section of the pipeline to be processed;

a determining module 1102, configured to determine 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 pipeline, the outer diameter information of the pipeline, and the maximum allowable pressure information of the pipeline section through a first relation calculation model;

the determining module 1102 is further configured to determine, through a second relationship calculation model, second radius information according to the information on the outer diameter of the pipeline and the information on the maximum allowable pressure of the pipeline section;

the determining module 1102 is further configured 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 a radius of an affected area when the pipe to be processed leaks.

The device provided by the embodiment of the application comprises a first relation calculation model for determining the radius of the natural gas pipeline leakage influence area, further, after acquiring the wind speed information of the environment where the pipeline which is leaked is positioned, the volume fraction information of sulfur-containing components in the natural gas transported in the pipeline, the correction coefficient information of the running pressure and the pipe diameter of the pipeline, the pipeline outer diameter information of the pipeline and the maximum allowable pressure information of a pipe section of the pipeline, determining first radius information and second radius information based on the corresponding information through a first relation calculation model and a second relation calculation model respectively, and further, target radius information, namely the radius of the natural gas pipeline leakage influence area is determined, and the radius information is determined without using a Gaussian model, so that the accuracy of the determined sulfur-containing natural gas pipeline leakage influence area is improved.

In one possible implementation, the first relational computation model is:

r₁＝[0.016ln(u)+0.024]x^1.5dp^0.5δ

wherein r is₁And the first radius information is u, the wind speed information is u, the volume fraction information of the sulfur-containing components is x, the outer diameter information of the pipeline is d, the maximum allowable pressure information of the pipeline section is p, and the correction coefficient information of the operating pressure and the pipe diameter is delta.

In one possible implementation, the second relational computation model is:

In a possible implementation manner, the determining module 1102 is configured to determine the largest radius information of the first radius information and the second radius information as the target radius information.

In a possible implementation manner, the obtaining module 1101 is configured to send an information obtaining request to a server, where the information obtaining 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 pipe outer diameter information, and the maximum allowable pressure information of the pipe segment;

It should be noted that: the determining apparatus for determining the pipeline leakage influence area provided in the above embodiment is only illustrated by dividing the above functional modules when determining the influence area of the sulfur-containing natural gas when the sulfur-containing natural gas pipeline leaks, and in practical applications, the above function distribution may be completed by different functional modules according to needs, that is, the internal structure of the terminal is divided into different functional modules, so as to complete all or part of the above described functions. In addition, the determination apparatus for the pipeline leakage affected area provided in the foregoing embodiment and the determination method for the pipeline leakage affected area belong to the same concept, and specific implementation processes thereof are detailed in the method embodiment and are not described herein again.

Fig. 12 is a schematic structural diagram of a terminal 1200 according to an embodiment of the present application, where the terminal 1200 may generate a relatively large difference due to a difference in configuration or performance, and may include one or more processors (CPUs) 1201 and one or more memories 1202, where the processors 1201 are very large scale integrated circuits, and are an operation core and a control core of the terminal 1200. Its functions are mainly to interpret computer instructions and to process data in computer software. The one or more memories 1202 have stored therein at least one program code that is loaded into and executed by the one or more processors 1201 to implement the methods provided by the various method embodiments described above. Certainly, the terminal 1200 may further have components such as a wired or wireless network interface, a keyboard, and an input/output interface, so as to perform input and output, and the terminal 1200 may further include other components for implementing device functions, which are not described herein again.

In an exemplary embodiment, a computer readable storage medium, such as a memory including program code, which is executable by a processor to perform the method of determining a pipe leak impact area in the above embodiments is also provided. For example, the computer-readable storage medium may 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, and the like.

In an exemplary embodiment, a computer program product or a computer program is also provided, which comprises computer program code stored in a computer readable storage medium, which is read by a processor of a terminal from the computer readable storage medium, which is executed by the processor, such that the terminal performs the method steps of the method for determining an area of influence of a duct leak provided in the above embodiments.

It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by hardware associated with program code, and the program may be stored in a computer readable storage medium, where the above mentioned storage medium may be a read-only memory, a magnetic or optical disk, etc.

The above description is only exemplary of the present application and should not be taken as limiting, as any modification, equivalent replacement, or improvement made within the spirit and principle of the present application should be included in the protection scope of the present application.

Claims

1. A method of determining an area of influence of a leak in a pipe, the method comprising:

determining second radius information according to the pipeline outer diameter information and the pipe section maximum allowable pressure information through a second relation calculation model;

and determining target radius information based on the first radius information and the second radius information, wherein the target radius information is used for indicating the radius of an affected area when the pipeline to be processed leaks.

2. The method of claim 1, wherein the first relational computation model is:

r₁＝[0.016ln(u)+0.024]x^1.5dp^0.5δ

wherein r is₁The first radius information is the first radius information, u is the wind speed information, x is the volume fraction information of the sulfur-containing components, d is the pipeline outer diameter information, p is the maximum allowable pressure information of the pipeline section, and delta is the correction coefficient information of the operating pressure and the pipe diameter.

3. The method of claim 1, wherein the second relational computation model is:

wherein r is₂And d is the second radius information, d is the outer diameter information of the pipeline, and p is the maximum allowable pressure information of the pipeline section.

4. The method of claim 1, wherein determining target radius information based on the first radius information and the second radius information comprises:

5. The method according to claim 1, wherein the acquiring of the wind speed information of the environment where 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 the 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 comprises:

sending an information acquisition request to a server, wherein the information acquisition request is used for acquiring the wind speed information, the volume fraction information of the sulfur-containing components, 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;

6. An apparatus for determining an area of influence of a leak in a pipe, the apparatus comprising:

the acquisition module is used for acquiring wind speed information of an environment where a pipeline to be processed is located, volume fraction information of sulfur-containing components in natural gas transported by the pipeline to be processed, correction coefficient information of 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 a pipe section of the pipeline to be processed:

the determining module is further configured to determine second radius information according to the pipeline outer diameter information and the pipe section maximum allowable pressure information through a second relation calculation model;

the determining module is further configured 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 a radius of an affected area when the to-be-processed pipeline leaks.

7. The apparatus of claim 6, wherein the first relational computation model is:

r₁＝[0.016ln(u)+0.024]x^1.5dp^0.5δ

wherein r is₁And the second radius information is the second radius information, u is the wind speed information, x is the volume fraction information of the sulfur-containing components, d is the pipeline outer diameter information, p is the maximum allowable pressure information of the pipeline section, and delta is the correction coefficient information of the operating pressure and the pipe diameter.

8. A system for determining an area of influence of a leak in a pipe, the system comprising:

the terminal is used for receiving the wind speed information, the volume fraction information of the sulfur-containing components, 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 pipeline section; determining first radius information based on the wind speed information, the volume fraction information of the sulfur-containing components, the correction coefficient information of the operating pressure and the pipeline, the outer diameter information of the pipeline and the maximum allowable pressure information of the pipeline section through a first relation calculation model; determining second radius information according to the pipeline outer diameter information and the pipe section maximum allowable pressure information through a second relation calculation model; determining target radius information based on the first radius information and the second radius information, wherein the target radius information is used for indicating the radius of an affected area when the pipeline to be processed leaks;

and the terminal is also used for alarming based on the target radius information.

9. A terminal, characterized in that the terminal comprises one or more processors and one or more memories having stored therein at least one program code, which is loaded and executed by the one or more processors to implement the operations performed by the method for determining a pipe leakage impact area according to any one of claims 1 to 4.

10. A computer-readable storage medium having at least one program code stored therein, the program code being loaded and executed by a processor to perform the operations performed by the method for determining a pipe leakage impact area according to any one of claims 1 to 4.