A gas flow indication method and system

Abstract

The application relates to the technical field of gas monitoring, in particular to a gas flow indication method and system. The method comprises the following steps: acquiring a differential pressure test section; acquiring differential pressure information according to the differential pressure test section; judging whether the differential pressure information meets preset differential pressure conditions; if the preset differential pressure conditions are met, corresponding differential pressure measuring points are acquired; acquiring corresponding pipe section information according to the differential pressure measuring points; analyzing the pipe section type of the pipe section information, setting corresponding differential pressure sampling points; acquiring target differential pressure according to the differential pressure sampling points; processing the target differential pressure according to preset differential pressure rules to generate a target gas flow rate; acquiring relationship curve data according to the target differential pressure and the target gas flow rate; and combining the relationship curve data and the pipe section information to generate a gas flow indication value. The gas flow indication method and system provided by the application have the effect of improving the gas flow indication performance in a pipeline.

Description

Technical Field

[0001] This application relates to the field of gas monitoring technology, and in particular to a gas flow indication method and system. Background Technology

[0002] With increasingly stringent requirements for controlling air pollution sources, the effective collection and transport of air pollutant gases has become a crucial control point, affecting both the emission reduction effect and the daily operating costs of the system.

[0003] Currently, many gas collection systems, such as those covering wastewater treatment facilities in many enterprises, have set up numerous gas collection points to collect polluting and odorous gases from different areas, and are equipped with complex gas collection and transportation pipeline systems.

[0004] Due to various reasons such as changes in the opening of regulating valves due to vibration, damage to gas collection devices due to gas corrosion, and blockage caused by the deposition of some substances in the gas, the gas collection system often experiences a significant deviation between the gas delivery flow rate and the design flow rate during actual operation. As a result, operators cannot obtain the flow information of the airflow in each pipeline in a timely manner and cannot make timely and effective adjustments and controls, leading to a deterioration in the overall collection effect. Summary of the Invention

[0005] To improve the indication performance of gas flow rate in pipelines, this application provides a gas flow rate indication method and system.

[0006] In a first aspect, this application provides a gas flow rate indication method, comprising the following steps:

[0007] Obtain the differential pressure test section;

[0008] Based on the differential pressure test section, obtain differential pressure information;

[0009] Determine whether the differential pressure information meets the preset differential pressure conditions;

[0010] If the preset differential pressure condition is met, the corresponding differential pressure measurement point is obtained;

[0011] Based on the differential pressure measuring points, obtain the corresponding pipe section information;

[0012] Analyze the pipe segment type based on the pipe segment information and set the corresponding differential pressure sampling points;

[0013] The target pressure difference is obtained based on the pressure difference sampling points.

[0014] The target pressure difference is processed according to a preset pressure difference rule to generate the target gas flow rate;

[0015] Based on the target pressure difference and the target gas flow rate, obtain the relationship curve data;

[0016] By combining the relationship curve data and the pipe segment information, a gas flow rate indication value is generated.

[0017] By adopting the above technical solution, it is determined whether the differential pressure information of the differential pressure test section in the pipeline meets the preset differential pressure conditions, so as to obtain the differential pressure measurement points corresponding to the differential pressure information that meets the preset differential pressure conditions. Further, based on the analysis of the pipe segment type of the pipe segment information where the differential pressure measurement points are located, the corresponding differential pressure sampling points are set, and the corresponding target differential pressure is obtained, thereby improving the accuracy of the obtained target differential pressure. The target differential pressure is processed using preset differential pressure rules to generate the target gas velocity. Combining the target differential pressure and the target gas velocity, the corresponding relationship curve data is obtained. Based on the actual situation of the pipe segment containing the pipeline, as well as the relationship curve data and pipe segment information, a gas flow indication value is generated, thereby improving the indication performance of gas flow in the pipeline.

[0018] Optionally, the step of analyzing the pipe segment information and setting corresponding differential pressure sampling points for the pipe segment type includes the following steps:

[0019] Determine the pipe segment type of the pipe segment information;

[0020] If it is a straight pipe section, the pipe diameter information is obtained, and the pressure difference sampling points of the straight pipe section are set according to the preset straight pipe setting rules and the pipe diameter information;

[0021] If it is a mixed pipe section, the mixed pipe information is obtained, and the differential pressure sampling points of the mixed pipe section are set according to the preset mixed pipe setting rules and the mixed pipe information.

[0022] By adopting the above technical solution, based on the actual pipe segment type in the pipe segment information, and further combining the corresponding differential pressure sampling points set by relevant setting rules, the accuracy of subsequent acquisition of target differential pressure is improved.

[0023] Optionally, setting the differential pressure sampling points of the mixing pipe section according to the preset mixing pipe setting rules and the mixing pipe information includes the following steps:

[0024] Based on the mixed pipe information, obtain the elbow port position information;

[0025] According to the preset mixing tube setting rules, the target distance standard is obtained;

[0026] Based on the target distance standard and the elbow port location information, the differential pressure sampling points of the mixed pipe section are set.

[0027] By adopting the above technical solution, the distance between the sampling point of the differential pressure in the mixed pipe section and the port of the elbow is set according to the target distance standard, which reduces the influence of eddy currents on pressure and thus ensures the accuracy of the pressure measurement values.

[0028] Optionally, processing the target pressure difference according to a preset pressure difference rule to generate the target gas flow rate includes the following steps:

[0029] Based on the pipe segment type in the pipe segment information, obtain the corresponding resistance coefficient;

[0030] Obtain the gas density of the pipe segment from the pipe segment information;

[0031] The target gas flow rate is generated by calculating the target pressure difference, the resistance coefficient, and the gas density of the pipe section according to the preset pressure difference rule.

[0032] By adopting the above technical solution, the target gas velocity can be estimated by using preset pressure difference rules based on the resistance coefficient, the gas density of the pipe section, and the corresponding target pressure difference.

[0033] Optionally, after obtaining the corresponding resistance coefficient based on the pipe segment type according to the pipe segment information, the following steps are included:

[0034] Based on the pipe segment type in the pipe segment information, obtain the corresponding pipe segment specification information;

[0035] The pipe section specification information and the resistance coefficient are calculated according to the preset resistance rules to generate the corresponding resistance coefficient.

[0036] By adopting the above technical solution and combining the specific specifications of the pipe segment in the pipe segment information to obtain the corresponding resistance coefficient, the accuracy of obtaining the resistance of various pipe segment types is improved.

[0037] Optionally, the pipe segment type of the pipe segment information includes straight pipe specification information and mixed pipe specification information. The step of obtaining the relationship curve data based on the target pressure difference and the target gas flow rate further includes the following steps:

[0038] Based on the straight pipe specification information, obtain the corresponding friction resistance.

[0039] Based on the specifications of the mixing tube, the corresponding local resistance is obtained;

[0040] The friction resistance and the local resistance are calculated according to the preset resistance rules to obtain the relationship curve data.

[0041] By adopting the above technical solution, the corresponding friction resistance and local resistance can be analyzed according to the specific pipe section type, thereby facilitating the acquisition of the relationship curve data between the target pressure difference and the target gas flow velocity.

[0042] Optionally, generating a gas flow indication value by combining the relationship curve data and the pipe segment information includes the following steps:

[0043] Based on the pipe segment information, the corresponding pipeline gas temperature is obtained;

[0044] Determine whether the gas temperature in the pipeline network exceeds a preset temperature difference threshold;

[0045] If the temperature difference is within the preset threshold, the relationship curve data is read and the gas flow rate indication value is generated.

[0046] If the preset temperature difference threshold is exceeded, the gas temperature in the pipeline network is divided into zones to generate target temperature zones.

[0047] Based on the target temperature zone, obtain the current gas temperature;

[0048] The target pressure difference and the current temperature are calculated according to the preset flow rules to generate the gas flow indication value.

[0049] By adopting the above technical solution, the gas temperature in the pipeline network that does not meet the preset temperature difference threshold is divided into zones, thereby reducing the occurrence of large errors in obtaining gas flow indication values.

[0050] Optionally, obtaining the current gas temperature based on the target temperature zone includes the following steps:

[0051] According to the preset duration standard, the temperature fluctuation value of the target temperature zone is obtained;

[0052] Determine whether the temperature fluctuation value exceeds a preset fluctuation threshold;

[0053] If the temperature fluctuation exceeds the preset fluctuation threshold, the target temperature zone is corrected, and the current gas temperature of the target temperature zone after correction is obtained until the temperature fluctuation value of the current gas temperature is within the preset fluctuation threshold.

[0054] By adopting the above technical solution, temperature correction is performed on target temperature zones that exceed the preset fluctuation threshold, which facilitates the improvement of the accuracy of obtaining gas flow indication values.

[0055] Optionally, after calculating the target pressure difference and the current temperature according to the preset flow rate rule to generate the gas flow rate indication value, the method further includes the following steps:

[0056] Based on the gas flow rate indication value, obtain the real-time gas flow rate value;

[0057] Determine whether the real-time gas flow rate value meets the preset flow rate deviation standard;

[0058] If the flow rate does not meet the preset deviation standard, an alarm signal is generated based on the real-time gas flow rate value.

[0059] By adopting the above technical solution, an alarm is triggered for real-time gas flow values ​​that do not meet the preset flow deviation standard, which facilitates alarming when abnormal gas flow occurs. On the other hand, the abnormal state corresponding to the gas flow can be obtained in real time through the real-time gas flow value.

[0060] Secondly, this application also provides a gas flow indication system, comprising:

[0061] The first acquisition module is used to acquire the differential pressure test section;

[0062] The second acquisition module is used to acquire differential pressure information based on the differential pressure test section;

[0063] The judgment module is used to determine whether the differential pressure information meets the preset differential pressure conditions;

[0064] If the preset differential pressure condition is met, the third acquisition module acquires the corresponding differential pressure measurement point.

[0065] The fourth acquisition module is used to acquire the corresponding pipe segment information based on the differential pressure measuring points;

[0066] The analysis module is used to analyze the pipe segment type of the pipe segment information and set the corresponding differential pressure sampling points;

[0067] The fifth acquisition module is used to acquire the target pressure difference based on the pressure difference sampling points;

[0068] The processing module is used to process the target pressure difference according to the preset pressure difference rules and generate the target gas flow rate;

[0069] The data module is used to acquire relationship curve data based on the target pressure difference and the target gas flow rate;

[0070] The generation module is used to combine the relationship curve data and the pipe segment information to generate a gas flow rate indication value.

[0071] By adopting the above technical solution, the judgment module determines whether the differential pressure information obtained by the second acquisition module in the differential pressure test section obtained by the first acquisition module in the pipeline meets the preset differential pressure conditions. This allows the third acquisition module to obtain the differential pressure measurement point corresponding to the differential pressure information that meets the preset differential pressure conditions, and the fourth acquisition module to obtain the corresponding pipe section information based on the differential pressure measurement point. Furthermore, the analysis module analyzes the pipe section type of the pipe section information where the differential pressure measurement point is located, sets the corresponding differential pressure sampling point, and combines it with the fifth acquisition module to obtain the corresponding target differential pressure, thereby improving the accuracy of the obtained target differential pressure. Then, the processing module processes the target differential pressure using preset differential pressure rules to generate the target gas flow rate. The data module combines the target differential pressure and the target gas flow rate to obtain the corresponding relationship curve data. Finally, the generation module generates a gas flow rate indication value based on the actual situation of the pipeline, the relationship curve data, and the pipe section information, thereby improving the indication performance of gas flow rate in the pipeline.

[0072] In summary, this application includes the following beneficial technical effects: determining whether the differential pressure information in the pipeline meets the preset differential pressure conditions, so as to obtain the differential pressure measurement points corresponding to the differential pressure information that meets the preset differential pressure conditions; further analyzing the pipe segment type of the pipe segment information based on the differential pressure measurement points, setting the corresponding differential pressure sampling points, and obtaining the corresponding target differential pressure, thereby improving the accuracy of the obtained target differential pressure; processing the target differential pressure using preset differential pressure rules to generate the target gas velocity; combining the target differential pressure and the target gas velocity to obtain the corresponding relationship curve data; and generating a gas flow indication value based on the actual situation of the pipe segment containing the pipeline, the relationship curve data, and the pipe segment information, thereby improving the indication performance of the gas flow in the pipeline. Attached Figure Description

[0073] Figure 1 This is an overall diagram of the gas collection system for a gas flow indication method according to this application.

[0074] Figure 2 This is a flowchart illustrating steps S101 to S109 of a gas flow indication method according to this application.

[0075] Figure 3 This is a flowchart illustrating steps S201 to S203 of a gas flow indication method according to this application.

[0076] Figure 4 This is a flowchart illustrating steps S301 to S303 in a gas flow indication method according to this application.

[0077] Figure 5 This is a flowchart illustrating steps S401 to S403 in a gas flow indication method according to this application.

[0078] Figure 6This is a flowchart illustrating steps S501 to S502 in a gas flow indication method according to this application.

[0079] Figure 7 This is a flowchart illustrating steps S601 to S604 of a gas flow indication method according to this application.

[0080] Figure 8 This is a pipeline pressure differential velocity relationship diagram for a gas flow indication method according to this application.

[0081] Figure 9 This is a pipeline pressure differential velocity relationship diagram for a gas flow indication method according to this application.

[0082] Figure 10 This is a flowchart illustrating steps S701 to S706 in a gas flow indication method according to this application.

[0083] Figure 11 This is a flowchart illustrating steps S801 to S803 in a gas flow indication method according to this application.

[0084] Figure 12 This is a flowchart illustrating steps S901 to S903 in a gas flow indication method according to this application.

[0085] Figure 13 This is a schematic diagram of a gas flow indication method according to this application.

[0086] Explanation of reference numerals in the attached figures:

[0087] 1. First acquisition module; 2. Second acquisition module; 3. Judgment module; 4. Third acquisition module; 5. Fourth acquisition module; 6. Analysis module; 7. Fifth acquisition module; 8. Processing module; 9. Data module; 10. Generation module. Detailed Implementation

[0088] The following is in conjunction with the appendix Figure 1-13 This application will be described in further detail.

[0089] For ease of explanation, as Figure 1 The diagram shows the overall structure of the gas collection system. In the diagram, 1 is the gas collection port, 2 is the micro differential pressure gauge, 3 is the fan, 4 is the condenser, 5 is the straight pipe section, 6 is the elbow pipe section, 7 is the pipe fitting (reducer), and 8 is the purification equipment.

[0090] The technology used in this solution is mainly based on the principle of fluid differential pressure. By measuring the fluid differential pressure in pipes and fittings with different pipe types, and then combining it with a pre-calibrated formula, the flow rate of the pipeline system can be monitored. It can be used to monitor the flow rate of the main pipe of the gas collection pipeline network system, the flow rate of each straight pipe, and the treatment air volume of the pollution treatment system. It can also be used for the flow balancing and debugging of relatively complex gas pipeline systems.

[0091] This application discloses a gas flow rate indication method, such as... Figure 2 As shown, it includes the following steps:

[0092] S101. Obtain the differential pressure test section;

[0093] S102. Obtain differential pressure information based on the differential pressure test section;

[0094] S103. Determine whether the differential pressure information meets the preset differential pressure conditions;

[0095] S104. If the preset differential pressure conditions are met, obtain the corresponding differential pressure measurement point;

[0096] S105. Obtain the corresponding pipe section information based on the differential pressure measuring points;

[0097] S106. Analyze the pipe segment type of the pipe segment information and set the corresponding differential pressure sampling points;

[0098] S107. Obtain the target differential pressure based on the differential pressure sampling points;

[0099] S108. Process the target pressure difference according to the preset pressure difference rule to generate the target gas flow rate;

[0100] S109. Obtain the relationship curve data based on the target pressure difference and the target gas flow rate;

[0101] S110. Combine the relationship curve data and pipe section information to generate a gas flow indication value.

[0102] In steps S101 to S104, the differential pressure test section refers to the differential pressure test section selected for flow monitoring of the pipeline in the gas pipeline network system according to the specific situation of the gas pipeline network system. The differential pressure information refers to the differential pressure value information between the differential pressure test sections in the pipeline. The preset differential pressure conditions refer to the differential pressure detection standards and detection location information specified in the pipeline monitoring system. The differential pressure measuring point refers to the differential pressure detection location in the differential pressure information that meets the preset differential pressure conditions.

[0103] For example, the differential pressure detection standard specified in the pipeline monitoring system is a differential pressure greater than or equal to 5 Pa. Differential pressure measuring points are set at the locations of pipe sections, pipe fittings, or various gas processing equipment connected in series according to the preset differential pressure conditions, and the differential pressure at the measuring points is greater than or equal to 5 Pa.

[0104] In order to improve the accuracy of obtaining differential pressure measurement points, the differential pressure measurement points are set at the cross-sections with the same pipe diameter. If a cross-section with the same diameter cannot be found before and after the pipe with the variable diameter, the problem can be solved by pipe diameter correction.

[0105] The pipe segment type in steps S105 to S106 refers to the pipe segment type information of the pipe segment in which it is located. The pipe segment type includes straight pipe, elbow and reducing pipe. The differential pressure sampling point refers to the sampling point selected from the pressure measurement points according to the specific situation of the pipe segment information.

[0106] In addition, differential pressure sampling points are set according to the accuracy of existing sensors, the actual conditions of each branch and main pipe of the pipeline network system, and the pre-set principles.

[0107] In steps S107 to S108, the target pressure difference refers to the total pressure difference value at the pressure difference sampling point, and the preset pressure difference rule refers to the pre-set formula and related data for calculating the target gas flow rate. The target gas flow rate refers to the gas flow rate in the pipeline.

[0108] The target pressure difference refers to the total pressure difference of the pipeline. Since the pipeline cross-section is measured by static pressure in this scheme, it is necessary to ensure that the dynamic pressure between the cross-sections is the same in order to obtain the corresponding total pressure difference.

[0109] Static pressure refers to the pressure exerted by gas on the surface of an object parallel to the airflow, which is the pressure that overcomes the resistance of the pipe; dynamic pressure refers to the pressure that converts the kinetic energy required for gas flow into pressure, which is the pressure that drives the gas forward.

[0110] Static pressure is the potential energy of a unit volume of gas, a force that compresses the gas and applies pressure to the pipe wall. The absolute static pressure of the gas in the pipe can be positive, higher than the surrounding atmospheric pressure, or negative, lower than the surrounding atmospheric pressure. Dynamic pressure is the kinetic energy of a unit volume of gas, also the first type of force. It causes the gas in the pipe to change its velocity. Dynamic pressure only acts in the direction of gas flow and is always positive.

[0111] Total pressure equals static pressure plus dynamic pressure. The pressure generated by the irregular movement of air molecules colliding with the pipe wall is called static pressure. In calculations, static pressure with absolute vacuum as the zero point is called absolute static pressure, and static pressure with atmospheric pressure as the zero point is called relative static pressure.

[0112] The relationship curve data in steps S109 to S110 refers to the relationship curve data between pipeline pressure difference and pipeline flow velocity obtained according to the pre-detection or preset pressure difference rules, the target pressure difference data and target gas flow velocity data and the corresponding pipe section information, and then the relationship curve data between pipeline pressure difference and pipeline flow velocity obtained according to the target pressure difference and target gas flow velocity corresponding to each specific pipe section; the gas flow indication value refers to the pipeline gas flow indication information obtained according to the relationship curve data or relevant gas flow calculation rules.

[0113] In actual gas flow rate detection and indication, there is often a significant deviation between the gas delivery flow rate and the design flow rate. This prevents operators from obtaining information on whether the airflow in the relevant pipelines is normal, hindering effective adjustment and control, and causing overall performance failure of the gas collection system. If a large number of gas flow meters are installed on the pipelines, the corrosiveness of the exhaust gas can cause the flow meters to malfunction. Manual testing, according to standard procedures, requires the opening of sampling holes with a preset diameter, such as a D75 sampling hole, and the testing workload is enormous, requiring specialized operating skills.

[0114] This embodiment provides a gas flow indication method. It determines whether the differential pressure information within the pipeline meets preset differential pressure conditions, thereby acquiring differential pressure measurement points corresponding to these conditions. Further analysis of the pipe segment information based on these measurement points, including the pipe segment type, allows for the setting of corresponding differential pressure sampling points and the acquisition of the target differential pressure. This improves the accuracy of the acquired target differential pressure. Preset differential pressure rules are then applied to process the target differential pressure, generating a target gas velocity. Combining the target differential pressure and target gas velocity, a corresponding relationship curve is obtained. This method generates gas flow indication values ​​based on the actual conditions of the pipe segment, the relationship curve data, and the pipe segment information, thus improving the indication performance of gas flow within the pipeline.

[0115] In one embodiment of this example, such as Figure 3 As shown, step S105 includes the following steps:

[0116] S201. Determine the pipe segment type based on the pipe segment information;

[0117] S202. If it is a straight pipe section, obtain the pipe diameter information and set the pressure difference sampling points of the straight pipe section according to the preset straight pipe setting rules and pipe diameter information.

[0118] S203. If it is a mixed pipe section, obtain the mixed pipe information and set the differential pressure sampling point of the mixed pipe section according to the preset mixed pipe setting rules and mixed pipe information.

[0119] In practical applications, pipe diameter information refers to the pipe diameter information of straight pipe sections, preset straight pipe setting rules refer to the rules for setting differential pressure sampling points for straight pipe sections, mixed pipe sections refer to mixed pipe sections of straight pipe sections and elbows, mixed pipe information refers to the number of elbows and the length and diameter information of straight pipe sections connecting the two ends of the elbows, and mixed pipe setting rules refer to the rules for setting differential pressure sampling points for pipe sections with both straight pipe sections and elbows.

[0120] The pressure taps of the differential pressure sampling points are set around the perimeter of the measuring pipe section at 225°, -0°, -13° and 5°, or around the perimeter of the rectangular pipe at 270°, -0° and -90°. For high humidity gas pressure taps, a U-shaped bottom drainage and liquid seal mechanism is set to reduce the accumulation of condensate that may clog the pressure taps and cause them to malfunction.

[0121] For example, if a certain pipe section only has straight pipes, obtain its corresponding pipe diameter information, and set corresponding pressure difference sampling points for the straight pipe section according to the preset straight pipe setting rules and the different pipe diameters. According to the preset straight pipe setting rules, the distance ratio between the pipe diameter of the straight pipe and the corresponding pressure difference sampling point is 1:10-1:100.

[0122] In the aforementioned application scenarios, based on the properties of the straight pipe, its diameter is 142cm. According to the preset straight pipe setting rules, the ratio of the pipe diameter to the distance of the corresponding differential pressure sampling point is 1:10. Therefore, the distance between the differential pressure sampling points of the straight pipe section in the straight pipe is 142cm×10=1420cm.

[0123] For example, a pipe section consists of straight pipes and elbows. According to the preset mixed pipe setting rules, the differential pressure sampling points of the mixed pipe section are set between 1 and 10 elbows, and the ratio of the length of the straight pipe connected to both ends of the elbow to the pipe diameter should be 1:1 to 1:20.

[0124] In the aforementioned application scenario, a certain pipe section has 9 bends. After relevant testing, it was found that the length of the straight pipe connected to both ends of the bend is 10cm and the diameter is 100cm. The corresponding pipe length to pipe diameter ratio is 1:10. Therefore, the differential pressure sampling point of the mixed pipe section is set between these 9 bends.

[0125] The gas flow indication method provided in this embodiment improves the accuracy of obtaining the target differential pressure from the differential pressure sampling points by further combining the actual pipe segment type in the pipe segment information with the corresponding differential pressure sampling points set by relevant setting rules.

[0126] In one embodiment of this example, such as Figure 4 As shown, step S203 includes the following steps:

[0127] S301. Obtain the elbow port location information based on the mixed pipe information;

[0128] S302. Obtain the target distance standard according to the preset mixing pipe setting rules;

[0129] S303. Based on the target distance standard and elbow port location information, set up differential pressure sampling points for the mixed pipe section.

[0130] In practical applications, mixed pipe information refers to the location of the differential pressure sampling point of the mixed pipe section and the port location information of each bend. The bend port location information refers to the location information of the ports at both ends of the bend. The preset mixed pipe setting rules refer to the pre-defined distance standards between the two port locations of the bend and the differential pressure sampling point of the mixed pipe section. The target distance standard refers to the distance standard between the bend port location and the nearest differential pressure sampling point of the mixed pipe section.

[0131] For example, based on the elbow port location information, the positions of the two ports of a certain mixed pipe section elbow can be obtained. Further, according to the preset mixed pipe setting rules, the target distance standard is that the distance between the differential pressure sampling point of the mixed pipe section and the elbow port is greater than or equal to 13cm. Therefore, the position of the differential pressure sampling point of the mixed pipe section is set to maintain a distance of 13cm or more from the positions of the two elbow ports.

[0132] The gas flow indication method provided in this embodiment sets the distance between the sampling point of the mixing pipe section pressure difference and the port of the elbow according to the target distance standard, which reduces the influence of eddies on pressure and thus ensures the accuracy of the pressure measurement value.

[0133] In one embodiment of this example, such as Figure 5 As shown, step S107 includes the following steps:

[0134] S401. Obtain the corresponding resistance coefficient based on the pipe segment type in the pipe segment information;

[0135] S402. Obtain the gas density of the pipe segment from the pipe segment information;

[0136] S403. Calculate the target pressure difference, resistance coefficient and gas density in the pipe section according to the preset pressure difference rules to generate the target gas flow rate.

[0137] In practical applications, the resistance coefficient refers to the resistance coefficient of straight pipes, elbows, reducing pipes, and related fittings; the pipe section gas density refers to the density of the gas in the pipe section, which can be obtained through the relevant gas density calculation formula; the preset pressure difference rule refers to the calculation formula between the target pressure difference, resistance coefficient, pipe section gas density, and target gas velocity.

[0138] For example, the calculation formula in the preset differential pressure rule is:

[0139]

[0140] Where ΔP refers to the target pressure difference, in Pa; ξ is the drag coefficient; ρ g Let be the gas density of the pipe section; v be the target gas velocity. The target pressure difference of the elbow section is 200 Pa, the resistance coefficient is 0.25, and the gas density of the pipe section is 1.25. Using the above formula, the target gas velocity can be estimated to be 35.7.

[0141] The gas flow indication method provided in this embodiment facilitates the estimation of the target gas flow rate by means of a preset pressure difference rule, based on the resistance coefficient, the gas density of the pipe section, and the corresponding target pressure difference.

[0142] In one embodiment of this example, such as Figure 6 As shown, step S401 includes the following steps:

[0143] S501. Obtain the corresponding pipe segment specification information based on the pipe segment type in the pipe segment information;

[0144] S502. Calculate the pipe section specification information according to the preset resistance rules and generate the corresponding resistance coefficient.

[0145] In practical applications, pipe segment specification information refers to the specification information of related pipes such as straight pipes, elbows, and reducing pipes. Preset resistance rules refer to the rules for calculating the corresponding resistance coefficient based on the specification information of related pipes such as straight pipes, elbows, and reducing pipes.

[0146] For example, the pipe segment information includes the pipe segment's length and diameter information. The preset resistance rule refers to the rule that calculates the corresponding resistance coefficient based on the pipe segment's length and diameter information. Then, the preset resistance rule is used to calculate the length and diameter information of a certain pipe segment to generate the corresponding resistance coefficient for that pipe segment.

[0147] The gas flow indication method provided in this embodiment obtains the corresponding resistance coefficient by combining the specific specification information of the pipe segment in the pipe segment information, thereby improving the accuracy of obtaining the pipe resistance of various pipe segment types.

[0148] In one embodiment of this example, such as Figure 7 As shown, the pipe segment specification information includes straight pipe specification information and mixed pipe specification information. Step S108 also includes the following steps:

[0149] S601. Obtain the corresponding friction resistance based on the straight pipe specification information;

[0150] S602. Obtain the corresponding local resistance based on the specifications of the mixing pipe;

[0151] S603. Calculate the friction resistance and local resistance according to the preset flow rules, and generate the corresponding target pressure difference and target gas velocity;

[0152] S604. Obtain the relationship curve data based on the target pressure difference and the target gas flow rate.

[0153] In practical applications, straight pipe specification information refers to the specification and size information of straight pipes, while mixed pipe specification information refers to the specification and size information of related pipe fittings such as elbows and reducing pipes.

[0154] The resistance to fluid flow in a pipeline can be divided into two types: friction resistance and local resistance. Friction resistance is the resistance generated by the internal friction of the fluid when it flows through a straight pipe of a certain diameter. Local resistance is mainly caused by the resistance caused by the fluid flowing through the fittings, valves, and sudden expansion or contraction of the pipe cross-section, etc., and is also known as shape resistance. The total resistance to fluid flow in a pipeline is the sum of friction resistance and local resistance.

[0155] Furthermore, due to the viscosity of air, a frictional force tangential to the surface of an object is generated. The resultant force of all frictional forces is called frictional drag. The drag resulting from the combined air pressure perpendicular to the surface of the object is called pressure drag. Under the conditions of neglecting viscosity and the absence of wake vortices, the pressure drag of an object in subsonic flow is zero.

[0156] In real fluids, viscosity not only generates frictional resistance but also causes the pressure distribution on the surface to differ from that in ideal fluids, resulting in differential pressure drag. For objects with good streamlines, in the absence of boundary separation, the differential pressure drag caused by viscosity is much smaller than the frictional drag.

[0157] For example, if a pipe section contains a straight pipe, the formula for calculating the friction loss along the pipe is: R = (λ / D)*(ν^2*γ / 2g), where ν is the flow velocity; λ is the resistance coefficient; γ is the gas density; D is the pipe diameter; R is the friction loss along the pipe; and g is the acceleration due to gravity. By using the straight pipe specifications, the corresponding pipe diameter and other relevant specifications can be obtained. Subsequently, by using the pressure difference sampling points of the straight pipe section, the corresponding target pressure difference and the corresponding target gas velocity can be obtained, and thus, the relevant relationship curve data can be derived. Figure 8 The figure shown is an example of the relationship between flow velocity and pressure difference in a straight pipe, where the straight pipe is a plastic pipe with a diameter of 500 mm.

[0158] For example, a pipe section may contain bends, reducers, and other related fittings. Fittings that change the cross-sectional area of ​​airflow (such as various reducers, duct inlets and outlets, valves), change the flow direction (elbows), or change the flow rate (such as tees, crosses, and side supply / exhaust vents of ducts) will generate local resistance. Local resistance is calculated using the following formula: Z = ξν²ρ / 2, where ξ is the local resistance coefficient, Z is the local resistance, and ρ is the air density inside the pipe. By analyzing the specifications of the mixed pipe sections, the corresponding pipe diameter and other relevant specifications can be obtained. Subsequently, by sampling the pressure difference at the mixed pipe section, the corresponding target pressure difference and target gas velocity can be obtained, leading to the generation of related relationship curves. Figure 9 The figure shown is an example of the relationship between flow velocity and pressure difference in a 90° bend pipe, where the resistance coefficient of a single bend is 0.25.

[0159] The gas flow indication method provided in this embodiment analyzes the corresponding friction resistance and local resistance according to the specific pipe section type, thereby facilitating the acquisition of the relationship curve data between the target pressure difference and the target gas flow velocity.

[0160] In one embodiment of this example, such as Figure 10 As shown, the pipe segment specification information includes straight pipe specification information and mixed pipe specification information. Step S109 also includes the following steps:

[0161] S701. Obtain the corresponding pipeline gas temperature based on the pipeline section information;

[0162] S702. Determine whether the gas temperature in the pipeline network exceeds the preset temperature difference threshold.

[0163] S703. If the temperature difference threshold is within the preset range, read the relationship curve data and generate a gas flow rate indication value.

[0164] S704. If the preset temperature difference threshold is exceeded, the gas temperature in the pipeline network will be divided into zones to generate target temperature zones.

[0165] S705. Obtain the current gas temperature according to the target temperature zone;

[0166] S706. Calculate the target pressure difference and current temperature according to the preset flow rules, and generate a gas flow indication value.

[0167] In practical applications, pipeline gas temperature refers to the temperature of the gas in each pipe section, preset temperature difference threshold refers to the relative deviation threshold of the pre-calibrated temperature difference, target temperature zoning refers to the area divided according to the temperature of each pipe section based on pre-set rules, and preset flow rules refer to the spreadsheet calculation system of the data center.

[0168] For example, if the relative deviation threshold of the pre-calibrated temperature difference is within 10% and the deviation between gas temperatures in the pipeline is 6%, then the relationship curve data is read, and the gas flow calibration curve is further calculated using the corresponding pipe diameter. The reading is then directly obtained from the gas flow calibration curve.

[0169] For example, if the deviation between gas temperatures in the pipeline network is found to be 11% after relevant temperature measurements, the gas temperature in the pipeline network is divided into zones. Then, the current temperature and target pressure difference of the target temperature zones are obtained based on the division of the target temperature zones. The current temperature and target pressure difference of the target temperature zones are then input into the spreadsheet calculation system of the data center to generate the corresponding gas flow indication value.

[0170] The gas flow indication method provided in this embodiment divides the gas temperature of the pipeline network into zones that do not meet the preset temperature difference threshold, thereby reducing the occurrence of large errors in obtaining gas flow indication values.

[0171] In one embodiment of this example, such as Figure 11 As shown, the pipe segment specification information includes straight pipe specification information and mixed pipe specification information. Step S705 also includes the following steps:

[0172] S801. Obtain the temperature fluctuation value of the target temperature zone according to the preset duration standard;

[0173] S802. Determine whether the temperature fluctuation value exceeds the preset fluctuation threshold.

[0174] S803. If the temperature fluctuation exceeds the preset fluctuation threshold, the target temperature zone is corrected, and the current gas temperature of the corrected target temperature zone is obtained until the temperature fluctuation value of the current gas temperature is within the preset fluctuation threshold.

[0175] In practical applications, the preset duration standard refers to the detection time period set for detecting gas temperature changes within the target temperature zone; the temperature fluctuation value refers to the amplitude of gas temperature changes within the target temperature zone; and the preset fluctuation threshold refers to the safe amplitude of gas temperature changes within the target temperature zone.

[0176] For example, if there is a large temperature difference in the gas in the pipeline network, the pipeline network is divided into temperature zones, generating multiple target temperature zones, and one gas temperature is set in each temperature zone. The preset duration standard is 1 hour, and the temperature fluctuation value is the temperature fluctuation value of the emitted gas within 1 hour is less than or equal to 10%. If the temperature fluctuation value of the target temperature zone is detected to be 11% during actual operation of the pipeline network, the temperature fluctuation value of the target temperature zone is corrected every 1 hour, and the current gas temperature of the target temperature zone after correction is obtained, until the temperature fluctuation value of the target temperature zone is less than or equal to 10%.

[0177] For example, if the temperature fluctuation value of the target temperature zone is detected to be 8% during actual operation of the pipeline network, the gas temperature of the pipeline network will be detected every hour and the detected gas temperature value will be displayed.

[0178] The gas flow indication method provided in this embodiment performs temperature correction on target temperature zones that exceed a preset fluctuation threshold, thereby improving the accuracy of obtaining gas flow indication values.

[0179] In one embodiment of this example, such as Figure 12 As shown, the following steps are included after step S706:

[0180] S901. Obtain the real-time gas flow rate value based on the gas flow rate indication value;

[0181] S902. Determine whether the real-time gas flow rate value meets the preset flow rate deviation standard;

[0182] S903. If the flow rate does not meet the preset deviation standard, an alarm signal will be generated based on the real-time gas flow rate value.

[0183] In practical applications, real-time gas flow rate refers to the real-time gas flow rate of the pipeline network during actual operation, while the preset flow rate deviation standard refers to the allowable deviation of the gas flow rate.

[0184] For example, according to the preset flow deviation standard, the gas flow deviation per minute should be less than or equal to 15%. According to the data center's spreadsheet calculation and display of the real-time gas flow in the pipeline, the gas flow deviation per minute is 18%. Then, the deviation value of the current real-time gas flow is obtained, and a corresponding alarm signal is generated based on the deviation value.

[0185] For example, if the real-time gas flow rate of the pipeline is calculated and displayed based on the spreadsheet in the data center, and the deviation of the gas flow rate per minute in the pipeline is 11%, then the deviation value of the current real-time gas flow rate can be obtained and displayed.

[0186] The gas flow indication method provided in this embodiment alarms for real-time gas flow values ​​that do not meet the preset flow deviation standard, thereby facilitating alarms when abnormal gas flow occurs. On the other hand, the abnormal state corresponding to the gas flow can be obtained in real time through the real-time gas flow value.

[0187] In the application scenario of the above-mentioned gas flow indication method, different methods can be used to indicate the gas flow in the pipeline network and monitor related data.

[0188] For example, in manual inspections, such as Figure 1As shown, for elbows 6, reducers 7, and equipment 2, 8 or straight pipe sections 5 in the pipeline system, pipe section total pressure measurement points are set on both sides, and micro differential pressure gauges 2 (or inclined tube level pressure gauges can be used) are installed. During system commissioning, the resistance coefficient calibration value, cross-sectional pressure difference and gas velocity curve of relevant pipe fittings and pipe sections are measured under operating conditions.

[0189] On the other hand, if there is a large temperature difference in the gas in the pipeline network, the pipeline network needs to be divided into temperature zones according to the relative deviation from the calibrated temperature difference, and one gas thermometer should be set in each temperature zone. When the pipeline network is actually running, the temperature and pressure difference data are read. First, it is determined whether the gas temperature differs from the calibrated operating temperature by more than 10%. If it is less than 10%, the reading can be directly taken from the flow calibration curve. If it exceeds 10%, the pressure difference and gas temperature can be directly entered into the spreadsheet to calculate the gas flow rate.

[0190] For example, in automatic measurement displays, such as Figure 1 As shown, for elbows 6, reducers 7, and equipment 2, 8, or straight pipe sections 5 in the pipeline system, total pressure measurement points are set on both sides of the pipe section, and digital micro differential pressure gauges 2 with wireless data transmission function are installed, and a data collection and processing center is set up. During system commissioning, the resistance coefficient calibration curves of relevant pipe fittings and sections under the measured operating conditions are compiled into an electronic spreadsheet. If there is a large temperature difference in the gas in the pipeline network, the pipeline network needs to be divided into temperature zones, and one gas thermometer is set up in each temperature zone.

[0191] During actual operation, the pipeline network reads the differential pressure data from the thermometer at the preset detection frequency as needed, calculates and displays the real-time flow of the gas in the pipeline network through the spreadsheet in the data center, and can issue an alarm when the flow deviation exceeds the preset flow deviation standard.

[0192] This embodiment also discloses a gas flow indication system, such as Figure 13 As shown, it includes:

[0193] The first acquisition module 1 is used to acquire the differential pressure test section;

[0194] The second acquisition module 2 is used to acquire differential pressure information based on the differential pressure test section;

[0195] The judgment module 3 is used to determine whether the differential pressure information meets the preset differential pressure conditions;

[0196] If the preset differential pressure condition is met, the third acquisition module 4 acquires the corresponding differential pressure measurement point.

[0197] The fourth acquisition module 5 is used to acquire the corresponding pipe segment information based on the differential pressure measuring point;

[0198] Analysis module 6 is used to analyze the pipe segment type of the pipe segment information and set the corresponding differential pressure sampling points;

[0199] The fifth acquisition module 7 is used to acquire the target pressure difference based on the pressure difference sampling points;

[0200] Processing module 8 is used to process the target pressure difference according to a preset pressure difference rule and generate a target gas flow rate;

[0201] Data module 9 is used to acquire relationship curve data based on the target pressure difference and the target gas flow rate;

[0202] The generation module 10 is used to generate a gas flow rate indication value by combining the relationship curve data and the pipe segment information.

[0203] By adopting the above technical solution, the judgment module 3 determines whether the differential pressure information obtained by the second acquisition module 2 in the differential pressure test section obtained by the first acquisition module 1 in the pipeline meets the preset differential pressure conditions. This allows the third acquisition module 4 to obtain the differential pressure measurement point corresponding to the differential pressure information that meets the preset differential pressure conditions, and the fourth acquisition module 5 to obtain the corresponding pipe section information based on the differential pressure measurement point. Furthermore, the analysis module 6 analyzes the pipe section type of the pipe section information where the differential pressure measurement point is located, sets the corresponding differential pressure sampling point, and combines it with the fifth acquisition module 7 to obtain the corresponding target differential pressure, thereby improving the accuracy of the obtained target differential pressure. Then, the processing module 8 processes the target differential pressure using preset differential pressure rules to generate the target gas flow rate. The data module 9 combines the target differential pressure and the target gas flow rate to obtain the corresponding relationship curve data. Finally, the generation module 10 generates a gas flow rate indication value based on the actual situation of the pipeline, the relationship curve data, and the pipe section information, thereby improving the indication performance of the gas flow rate in the pipeline.

[0204] It should be noted that the system provided in this application embodiment also includes each module and / or corresponding sub-module corresponding to the logical function or logical step of any of the above-mentioned gas flow indication methods, to achieve the same effect as each logical function or logical step, which will not be elaborated here.

[0205] The above are all preferred embodiments of this application and are not intended to limit the scope of protection of this application. Therefore, all equivalent changes made in accordance with the structure, shape and principle of this application should be covered within the scope of protection of this application.

Claims

1. A gas flow rate indication method, characterized in that, Includes the following steps: Obtain the differential pressure test section; Based on the differential pressure test section, obtain differential pressure information; Determine whether the differential pressure information meets the preset differential pressure conditions; If the preset differential pressure condition is met, the corresponding differential pressure measurement point is obtained; Based on the differential pressure measuring points, obtain the corresponding pipe section information; Analyze the pipe segment type based on the pipe segment information and set the corresponding differential pressure sampling points; The target pressure difference is obtained based on the pressure difference sampling points. The target pressure difference is processed according to a preset pressure difference rule to generate the target gas flow rate; Based on the target pressure difference and the target gas flow rate, obtain the relationship curve data; By combining the relationship curve data and the pipe segment information, a gas flow rate indication value is generated; The differential pressure test section refers to the differential pressure test section selected for flow monitoring of the pipeline in the gas pipeline network system according to the specific situation of the gas pipeline network system. The differential pressure information refers to the differential pressure value information between the differential pressure test sections in the pipeline. The preset differential pressure conditions refer to the differential pressure detection standards and detection location information specified in the pipeline monitoring system. The differential pressure measuring point refers to the differential pressure detection location in the differential pressure information that meets the preset differential pressure conditions. The process of analyzing the pipe segment information and setting corresponding differential pressure sampling points for the pipe segment type includes the following steps: Determine the pipe segment type of the pipe segment information; If it is a straight pipe section, the pipe diameter information is obtained, and the pressure difference sampling points of the straight pipe section are set according to the preset straight pipe setting rules and the pipe diameter information; If it is a mixed pipe section, the mixed pipe information is obtained, and the differential pressure sampling points of the mixed pipe section are set according to the preset mixed pipe setting rules and the mixed pipe information; Setting the differential pressure sampling points of the mixing pipe section according to the preset mixing pipe setting rules and the mixing pipe information includes the following steps: Based on the mixed pipe information, obtain the elbow port position information; According to the preset mixing tube setting rules, the target distance standard is obtained; Based on the target distance standard and the elbow port location information, the differential pressure sampling points of the mixed pipe section are set.

2. The gas flow rate indication method according to claim 1, characterized in that, The step of processing the target pressure difference according to the preset pressure difference rule to generate the target gas flow rate includes the following steps: Based on the pipe segment type in the pipe segment information, obtain the corresponding resistance coefficient; Obtain the gas density of the pipe segment from the pipe segment information; The target gas flow rate is generated by calculating the target pressure difference, the resistance coefficient, and the gas density of the pipe section according to the preset pressure difference rule.

3. The gas flow rate indication method according to claim 2, characterized in that, The step of obtaining the corresponding resistance coefficient based on the pipe segment type according to the pipe segment information includes the following steps: Based on the pipe segment type in the pipe segment information, obtain the corresponding pipe segment specification information; The pipe section specification information is calculated according to the preset resistance rules to obtain the corresponding resistance coefficient.

4. The gas flow rate indication method according to claim 1, characterized in that, The pipe segment information includes straight pipe specification information and mixed pipe specification information. The step of obtaining the relationship curve data based on the target pressure difference and the target gas flow rate further includes the following steps: Based on the straight pipe specification information, obtain the corresponding friction resistance. Based on the specifications of the mixing tube, the corresponding local resistance is obtained; The friction resistance and the local resistance are calculated according to the preset flow rules to obtain the relationship curve data.

5. A gas flow rate indication method according to claim 1, characterized in that, The process of generating a gas flow rate indication value by combining the relationship curve data and the pipe segment information includes the following steps: Based on the pipe segment information, the corresponding pipeline gas temperature is obtained; Determine whether the gas temperature in the pipeline exceeds a preset temperature difference threshold; If the preset temperature difference threshold is not exceeded, the relationship curve data is read and the gas flow rate indication value is generated. If the preset temperature difference threshold is exceeded, the gas temperature in the pipeline network is divided into zones to generate target temperature zones. Based on the target temperature zone, obtain the current gas temperature; The target pressure difference and the current gas temperature are calculated according to the preset flow rules to generate the gas flow indication value.

6. A gas flow rate indication method according to claim 5, characterized in that, The step of obtaining the current gas temperature based on the target temperature zone includes the following steps: According to the preset duration standard, the temperature fluctuation value of the target temperature zone is obtained; Determine whether the temperature fluctuation value exceeds a preset fluctuation threshold; If the temperature fluctuation exceeds the preset fluctuation threshold, the target temperature zone is corrected, and the current gas temperature of the target temperature zone is obtained after correction, until the temperature fluctuation value of the current gas temperature is within the preset fluctuation threshold.

7. A gas flow rate indication method according to claim 5, characterized in that, After calculating the target pressure difference and the current temperature according to the preset flow rate rule and generating the gas flow rate indication value, the following steps are also included: Based on the gas flow rate indication value, obtain the real-time gas flow rate value; Determine whether the real-time gas flow rate value meets the preset flow rate deviation standard; If the flow rate does not meet the preset deviation standard, an alarm signal is generated based on the real-time gas flow rate value.

8. A gas flow rate indication system, characterized in that, include: The first acquisition module (1) is used to acquire the differential pressure test section; The second acquisition module (2) is used to acquire differential pressure information based on the differential pressure test section; The judgment module (3) is used to determine whether the differential pressure information meets the preset differential pressure conditions; If the preset differential pressure condition is met, the third acquisition module (4) acquires the corresponding differential pressure measurement point. The fourth acquisition module (5) is used to acquire the corresponding pipe section information based on the differential pressure measuring point; Analysis module (6) is used to analyze the pipe segment type of the pipe segment information and set the corresponding differential pressure sampling points; The fifth acquisition module (7) is used to acquire the target pressure difference based on the pressure difference sampling points; The processing module (8) is used to process the target pressure difference according to the preset pressure difference rules and generate the target gas flow rate; Data module (9) is used to obtain relationship curve data based on the target pressure difference and the target gas flow rate; The generation module (10) is used to generate a gas flow indication value by combining the relationship curve data and the pipe segment information.

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