A natural gas pipeline pressure drop rate anti-explosion pipe detection technology system device

Abstract

The utility model discloses a natural gas pipeline pressure drop rate explosion -proof pipe detection technical system device, including station control unit, controller unit and field measurement unit, a station site is provided with a controller unit and a field measurement unit, the field measurement unit of being located same station site with controller unit communication connection, each controller unit of being located different station site is connected with station control unit communication respectively, each field measurement unit of being located different station site respectively obtains the state information of gas pipeline at different station site and sends state information to with field measurement unit located same station site controller unit. The utility model discloses a natural gas pipeline pressure drop rate explosion -proof pipe detection technical system device, has realized the centralized monitoring and distributed fast response of multiple station site gas pipeline, has effectively promoted the emergency disposal efficiency and system automation management level of the pipe explosion accident, possesses high reliability and real -time nature.

Description

Technical Field

[0001] This utility model relates to the field of gas transmission and distribution safety monitoring technology, specifically a natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device. Background Technology

[0002] In modern industrial production, accurately grasping the production situation is the foundation for achieving scientific scheduling and safety management. For production processes with relatively centralized layouts, local control, monitoring, and wiring methods can usually be adopted, or distributed control systems (DCS), programmable logic controllers (PLCs), and dedicated controllers can be selected to achieve effective monitoring. However, for systems with extremely wide distribution of production links, such as natural gas pipelines, oil fields, long-distance pipelines, regional power grids, and water supply networks, the distance between stations often reaches several kilometers to thousands of kilometers. If traditional DCS or PLC systems are still used for centralized wiring and control, a series of technical problems will be faced, such as complex line laying, high construction costs, and excessively long signal transmission distances leading to a decrease in stability and real-time performance. It is difficult to meet the requirements of large-scale distributed monitoring for reliability and response speed.

[0003] In the field of gas transmission and distribution, the above problems are particularly prominent. Existing technologies lack effective means for unified, real-time status monitoring and rapid response of gas pipeline networks with wide distribution areas and scattered stations. Dispatch centers often cannot obtain key pipeline status information such as pressure and flow at each remote station in real time, making it difficult for dispatchers to detect abnormal conditions in a timely and accurate manner and to determine the location and nature of accidents. Once a gas pipeline bursts or has a serious leak, failure to achieve rapid location and emergency shut-off will lead to continuous leakage of natural gas, which will not only cause resource waste and economic losses, but may also trigger secondary disasters such as fires and explosions, seriously threatening public safety and national property security.

[0004] Therefore, there is an urgent need to build a burst pipe protection system that can adapt to the characteristics of wide-area distribution and has high real-time performance and high reliability, so as to realize centralized monitoring and rapid linkage control of dispersed stations and make up for the shortcomings of existing technologies in long-distance, distributed application scenarios. Utility Model Content

[0005] The purpose of this invention is to provide a natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device to solve the problems mentioned in the background art.

[0006] To achieve the above objectives, this utility model provides the following technical solution: a natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device, including a station control unit, a controller unit, and a field metering unit, wherein one controller unit and one field metering unit are installed at a station; The field metering unit located at the same station is communicatively connected to the controller unit, and each controller unit located at a different station is communicatively connected to the station control unit. Each of the field metering units located at different stations acquires the status information of the gas pipeline at different stations and sends the status information to the controller unit located at the same station as the field metering unit. Each of the controller units located at different stations sends the received status information of the gas pipeline at each station to the station control unit. When the station control unit receives a status information of a gas pipeline at a station that is less than a preset status information, the station control unit outputs a first control signal to the controller unit corresponding to that station, and controls the controller unit corresponding to that station to output a second control signal to the field metering unit.

[0007] Specifically, the field metering unit includes a temperature acquisition unit, a flow acquisition unit, a switching unit, and a pressure acquisition unit; The flow acquisition unit, the pressure acquisition unit, the switch unit, and the temperature acquisition unit are respectively installed on the gas distribution pipeline at the station; The flow acquisition unit obtains the flow information of the gas distribution pipeline at the station; The pressure acquisition unit obtains pressure information from the gas distribution pipeline at the station. The temperature acquisition unit obtains the temperature information of the gas distribution pipeline at the station.

[0008] Specifically, the flow acquisition unit sends the flow information to the controller unit, the pressure acquisition unit sends the pressure information to the controller unit, the temperature acquisition unit sends the temperature information to the controller unit, and each controller unit located at different stations sends the received flow, pressure, and temperature information of the gas pipeline to the station control unit respectively.

[0009] Specifically, when the station control unit receives information that the flow rate of the gas pipeline at a station is less than a preset flow rate and / or the pressure is less than a preset pressure, it outputs a first control signal to the controller unit corresponding to that station, and controls the controller unit corresponding to that station to output a second control signal to control the switch unit to turn off.

[0010] Specifically, the on-site metering unit further comprises a flow calculation unit, which is communicatively connected to the station control unit. The flow calculation unit calculates standard flow information corresponding to the flow information according to the temperature information, the pressure information and the flow information. The on-site metering unit further comprises an early warning unit, which is communicatively connected to the station control unit and configured to output an early warning signal when the flow information is less than preset flow information and / or the pressure information is less than preset pressure information.

[0011] Specifically, the on-site metering unit further comprises a display unit, which is communicatively connected to the station control unit and configured to display the flow information, the pressure information, the temperature information and the state information of the switch unit.

[0012] Compared with the prior art, the beneficial effects of the utility model are as follows: The present case provides a natural gas pipeline pressure drop rate anti-explosion detection technology system, hereinafter referred to as "the system". The system aims to solve the technical problems such as poor monitoring real-time performance and slow pipe burst response caused by long distance and difficult wiring of wide-area distributed gas pipe networks. The system adopts a hierarchical distributed control architecture to realize centralized monitoring and rapid linkage control of dispersed stations.

[0013] The core composition of the system includes a three-level structure: a station control unit located in the monitoring center, at least one controller unit deployed at each remote station, and an on-site metering unit arranged in a matching manner with each controller unit. Each station is independently configured with a set of controller unit and on-site metering unit to form an autonomous local monitoring node. This "one station, one unit" configuration mode ensures the independence of data acquisition and control at each station.

[0014] The communication connection relationship is as follows: the on-site metering unit and the controller unit located at the same station establish a reliable communication connection through an industrial field bus (such as PROFIBUS-DP, Modbus RTU) or a hard-wiring mode. Each controller unit distributed in different stations establishes a data link with the central station control unit through a long-distance communication mode such as industrial Ethernet, 4G / 5G wireless private network or satellite communication. This hybrid communication architecture not only ensures the real-time performance of local communication, but also solves the reliability problem of long-distance transmission.

[0015] The working principle of the system is based on the distributed collection of state information and the centralized decision-making mechanism. The on-site metering unit of each station continuously collects multiple types of state parameters of the gas pipeline in the station area, including but not limited to key process variables such as pressure, flow rate and temperature. These state information are first sent to the controller unit of the same station for preliminary processing and caching, and then collected to the station control unit by each controller unit through the remote communication network.

[0016] As the intelligent decision-making center of the system, the station control unit has a built-in expert algorithm library to perform real-time analysis and pattern recognition on the received network status information. When the pipeline status information at a certain station is detected to be lower than the preset safety threshold, the station control unit immediately generates the first control command and sends it to the controller unit at the corresponding station through the remote communication link. After receiving the command, the controller unit quickly converts it into a second control signal to drive the actuator in the local field metering unit to realize the rapid shut-off or regulation of the valve, thereby forming a complete monitoring-decision-execution closed loop.

[0017] Detailed design of field metering unit As the end-point sensing and execution mechanism of the system, the completeness of the design of the field metering unit directly determines the reliability of the entire system. The unit consists of four core subsystems: pressure acquisition unit, flow acquisition unit, temperature acquisition unit, and switch unit. Each subsystem is designed according to industrial-grade protection standards to adapt to the harsh working environment of gas stations.

[0018] The pressure acquisition unit uses a high-precision pressure sensor with a measurement range of -0.1 to 10 MPa and an accuracy class of 0.075. It can capture subtle changes in pipeline pressure in real time. The sensor adopts the diffusion silicon or capacitive measurement principle and is equipped with an automatic temperature compensation function to ensure the accuracy of the measurement value across the entire temperature range. The installation location is preferably on a straight section of the pipeline to avoid the influence of valves, elbows and other turbulent components on the measurement accuracy.

[0019] The flow acquisition unit consists of a flow meter and its signal conditioning circuit. Considering the characteristics of natural gas metering, a gas turbine flow meter or an ultrasonic flow meter is preferred. The turbine flow meter is suitable for medium and low pressure conditions, with an accuracy of up to 1.0 grade; the ultrasonic flow meter is suitable for high pressure and high flow scenarios, and has no moving parts, allowing for long maintenance cycles. The flow meter has a built-in microprocessor that can calculate the operating flow rate in real time and output a standard signal via an RS-485 interface.

[0020] The temperature acquisition unit uses a Pt100 platinum resistance temperature sensor with a measurement range of -50 to 150℃ and an accuracy class of A. The sensor is installed in a temperature sensing sleeve, the sleeve material of which is matched with the pipe material to avoid measurement errors caused by differences in thermal expansion coefficients. The temperature measurement point is located upstream of the flow meter to ensure the accuracy of temperature compensation in flow calculation.

[0021] The switching unit, as the final actuator, has an explosion-proof electric ball valve as its core component. The ball valve diameter is determined according to the pipeline size, with common specifications ranging from DN50 to DN300. The valve adopts a fire-resistant and anti-static design, and the sealing material is polytetrafluoroethylene (PTFE) or reinforced PTFE, ensuring long-term sealing performance in gaseous media. The electric actuator is equipped with a manual operation function, allowing for emergency operation in case of power failure or other abnormal situations.

[0022] System workflow and voltage drop detection algorithm The system's workflow is based on real-time monitoring and intelligent judgment of status information. The field metering units located at each station continuously collect pipeline operating parameters: the pressure acquisition unit obtains the absolute pressure value of the pipeline with a sampling period of 100ms; the temperature acquisition unit monitors the gas temperature synchronously; and the flow acquisition unit measures the operating flow rate in real time. After local signal conditioning and A / D conversion, these raw data are transmitted to the controller unit at the same station via the fieldbus.

[0023] The controller unit preprocesses the received raw data, including digital filtering, dimension conversion, and preliminary validity checks. The preprocessed data is timestamped and identified by the station, encapsulated into standard communication frames, and sent to the station control unit through the remote communication network. The communication protocol adopts the industry standard IEC 104 or DNP3.0 protocol to ensure the reliability and real-time performance of data transmission.

[0024] The core of the station control unit's data processing is the pressure drop rate detection algorithm. The algorithm first performs a moving average filter on the received pressure data sequence to eliminate random interference, and then calculates the pressure change rate per unit time. ΔP / Δt = (P t - P t-1 ) / Δt Where P t P is the current pressure sample value. t-1 Δt represents the pressure value at the previous sampling time, and Δt represents the sampling interval.

[0025] The system has two preset pressure thresholds: a primary warning threshold and a secondary shutdown threshold. When the pressure drop rate is detected to continuously exceed 0.15 MPa / min and the absolute pressure value is lower than 85% of the preset working pressure, a warning state is triggered. When the pressure drop rate exceeds 0.3 MPa / min or the absolute pressure value is lower than 70% of the preset working pressure, an emergency shutdown logic is immediately triggered.

[0026] In terms of flow monitoring, the system introduces a flow calculation unit to perform temperature and pressure compensation, converting the operating flow rate into the standard flow rate under standard conditions: Q n = Qᵥ × (P a / P n ) × (T n / T a ) Q n Where Qᵥ is the standard flow rate and Pᵥ is the operating flow rate. a For actual pressure, P n T is the standard atmospheric pressure. a T represents the actual temperature. nThe standard temperature is used. This compensation ensures the accuracy of flow monitoring and avoids misjudgments caused by temperature and pressure changes.

[0027] System response mechanism and linkage control When the station control unit identifies an abnormal operating condition through the pressure drop detection algorithm, it immediately activates the tiered response mechanism. The system first performs fault location by comparing the pressure gradient and flow balance of each station to accurately pinpoint the pipe section where the pipe burst occurred.

[0028] For anomalies at the warning level, the station control unit outputs the first control signal to the warning unit, triggering the audible and visual alarm device. At the same time, the abnormal station is highlighted on the monitoring screen, and the warning signal is automatically pushed to the on-duty personnel through the dispatch telephone system, providing detailed abnormal parameters and handling suggestions.

[0029] When the emergency shutdown conditions are met, the station control unit immediately generates the first control signal and sends it to the controller unit at the accident site through the redundant communication channel. After receiving the instruction, the controller unit converts it into the second control signal within 100ms, driving the electric ball valve in the switching unit to perform the shutdown action. The valve's action time from fully open to fully closed is controlled within the range of 5 to 15 seconds depending on the pipe diameter, ensuring both rapid shut-off and avoiding water hammer effect.

[0030] The system is specially designed with a shutdown confirmation mechanism. After the valve performs the shutdown action, the valve position sensor in the field metering unit provides real-time feedback on the valve position status, and the pressure acquisition unit continues to monitor the pressure changes after shutdown. This confirmation information is fed back to the station control unit through the controller unit, forming a complete control closed loop. If the downstream pressure continues to drop abnormally after shutdown, the system will determine that the main valve shutdown has failed and automatically activate the ESD emergency shutdown system to shut down the valves of relevant upstream and downstream stations.

[0031] Optional System Implementation Methods and Optimization Designs On top of the basic architecture, the system offers multiple optional functional modules that users can flexibly configure according to their actual needs.

[0032] As an important optional component, the flow calculation unit adopts a 32-bit floating-point DSP processor. In addition to performing basic temperature and pressure compensation calculations, it also has advanced functions such as flow accumulation, hourly peak and valley recording, and daily and monthly report generation. The calculation unit is connected to the station control unit through an Ethernet interface and provides a Modbus TCP protocol interface for easy integration with third-party systems.

[0033] The early warning unit provides multi-level alarm management functions. In addition to basic audible and visual alarms, it also supports various alarm methods such as SMS push notifications, email notifications, and WeChat mini-program reminders. The alarm levels are divided into four levels: prompt, warning, alarm, and emergency, corresponding to different handling procedures and notification scopes.

[0034] The controller unit is installed in an explosion-proof certified control cabinet with an IP65 protection rating, suitable for Zone 1 explosive gas environments. The control cabinet is equipped with dual redundant power supply modules, supporting automatic switching between AC220V and DC24V dual power supplies to ensure continuous system operation in case of power failure. The cabinet layout adopts a strong and weak current separation design, with signal lines and power lines run separately to effectively avoid electromagnetic interference.

[0035] The display unit serves as the human-machine interface, employing an industrial-grade touchscreen available in sizes ranging from 10 to 21 inches. The screen displays a real-time diagram of the entire network's process flow, using different colors to indicate the operating status of each station. It supports functions such as historical data curve querying, alarm record retrieval, and operation log auditing, providing data support for operational analysis.

[0036] The system communication network adopts a multi-level redundancy design. The field layer adopts an RS-485 bus ring network architecture, so that the failure of any node will not affect the communication of other nodes. The remote layer adopts dual-carrier link hot standby, with an automatic switching delay of less than 200ms. All communication interfaces are equipped with opto-isolation protection to prevent ground potential difference from damaging the equipment.

[0037] This system enables 24 / 7 monitoring and intelligent protection of a wide-area distributed gas pipeline network, significantly improving the safety and reliability of pipeline operation and providing effective technical support for long-distance natural gas transportation. Attached Figure Description

[0038] Figure 1 This is a schematic diagram of the structure of the first natural gas pipeline pressure drop rate explosion-proof pipe detection technology of this utility model; Figure 2 This is a schematic diagram of the structure of the second type of explosion-proof pipe for detecting pressure drop rate in natural gas pipelines according to this utility model; Figure 3 This is a schematic diagram of the structure of the third type of explosion-proof pipe detection technology for natural gas pipeline pressure drop rate according to this utility model. Detailed Implementation

[0039] The technical solutions of the present utility model will be clearly and completely described below with reference to the accompanying drawings of the embodiments. Obviously, the described embodiments are only some embodiments of the present utility model, and not all embodiments. Based on the embodiments of the present utility model, all other embodiments obtained by those of ordinary skill in the art without creative effort are within the protection scope of the present utility model.

[0040] Example 1 Please see Figure 1, the present utility model provides a technical solution: a natural gas pipeline pressure drop rate anti-explosion tube detection technical system device, the station gas pipe burst protection system comprises: a station control unit 10, at least one controller unit 20 ( Figure 1 exemplarily representing n controller units 20) and at least one field metering unit 30 ( Figure 1 exemplarily representing n field metering units 30), a controller unit 20i and a field metering unit 30i are provided at a station Ai (where 1=<i=<n), the field metering unit 30 located at the same station is communicatively connected with the controller unit 20, each controller unit 20 located at a different station is communicatively connected with the station control unit 10 respectively, each field metering unit 30 located at a different station acquires the state information of the gas pipeline at the different station respectively and sends the state information to the controller unit 20 located at the same station as the field metering unit 30, each controller unit 20 located at a different station sends the received state information of the gas pipeline at each station to the station control unit 10, when the station control unit 10 receives that the state information of the gas pipeline at a station is less than the preset state information, the station control unit 10 outputs a first control signal to the controller unit 20 corresponding to that station, and controls the controller unit 20 corresponding to that station to output a second control signal to the field metering unit 30.

[0041] as Figure 1 shown, the station gas pipe burst protection system comprises a station control unit 10, at least one controller unit 20 and at least one field metering unit 30 ( Figure 1 exemplarily representing n controller units 20 and n field metering units 30), each station Ai is provided with one controller unit 20i and one field metering unit 30i, the field metering unit 30 located at the same station is communicatively connected with the controller unit 20, each controller unit 20 located at a different station is communicatively connected with the station control unit 10 respectively, for example, the first station A1 is provided with a controller unit 201 and a field metering unit 301, the field metering unit 301 is communicatively connected with the controller unit 201, the second station A2 is provided with a controller unit 202 and a field metering unit 302, the field metering unit 302 is communicatively connected with the controller unit 202, ..., the nth station An is provided with a controller unit 20n and a field metering unit 30n, the field metering unit 30n is communicatively connected with the controller unit 20n, the controller unit 201 at the first station A1, the controller unit 202 at the second station A2, ... the controller unit 20n at the nth station An are respectively communicatively connected with the station control unit 10.

[0042] Each field metering unit 30 located at different stations acquires the status information of the gas pipeline at its respective station and sends the status information to the controller unit 20 located at the same station as the field metering unit 30. Specifically, the field metering unit 301 at the first station A1 acquires the status information of the gas pipeline at the first station A1 and sends it to the controller unit 201 at the first station A1; the field metering unit 302 at the second station A2 acquires the status information of the gas pipeline at the second station A2 and sends it to the controller unit 202 at the second station A2; ..., the field metering unit 30n at the nth station An acquires the status information of the gas pipeline at the nth station An and sends it to the controller unit 20 at the nth station A1. The status information of the gas pipeline at point n is sent to the controller unit 20n set at point n An. After the controller units 20 at the first station A1 to the nth station An respectively obtain the status information of the gas pipeline corresponding to that station, each controller unit 20 located at different stations sends the received status information of the gas pipeline at each station to the station control unit 10. That is, the controller unit 201 set at the first station A1 sends the obtained status information of the gas pipeline at the first station A1 to the station control unit 10, the controller unit 202 set at the second station A2 sends the obtained status information of the gas pipeline at the second station A2 to the station control unit 10, ... the controller unit 20n set at the nth station An sends the obtained status information of the gas pipeline at the nth station An to the station control unit 10.

[0043] After receiving the status information of gas pipelines at different stations, the station control unit 10 analyzes the relationship between the status information of the gas pipelines at different stations and preset status information. When the status information of the gas pipeline at at least one station is less than the preset status information, the station control unit 10 outputs a first control signal to the controller unit 20 corresponding to that station. The first controller unit 20 then outputs a second control signal to the field metering unit 30 to control the field metering unit 30. For example, if the gas pipeline at the second station A2 experiences a rupture, some natural gas will leak after the rupture. The flow or pressure values ​​may change, meaning the flow or pressure information of the gas pipeline at the second station A2 will decrease. The status information of the gas pipeline at the second station A2 received by the station control unit 10 will be less than the preset status information. At this time, the station control unit 10 outputs a first control signal to the controller unit 202 set in the second station A2, controlling the controller unit 202 set in the second station A2 to output a second control signal to the field metering unit 302, thereby realizing the control of the field metering unit 302 at the second station A2. The control of the field metering unit 302 can be to close the gas pipeline valve at the second station A2 to prevent more natural gas leakage.

[0044] It should be noted that, in the above embodiment, when the status information of the gas pipeline at the second station A2 is less than the preset status information, a first control signal is output to the controller unit 202 corresponding to the second station A2, and the controller unit 202 corresponding to the second station A2 outputs a second control signal to the field metering unit 302 in the second station A2. In other possible embodiments, there may be situations where the status information of the gas pipelines at multiple stations is less than the preset status information. For example, when the status information of the gas pipeline at the second station A2 obtained by the station control unit 10 is less than the preset status information, and the status information of the gas pipeline at the nth station An is less than the preset status information, at this time, the station control unit 10 outputs the first control signal to the controller unit 202 corresponding to the second station A2 and the controller unit 20n corresponding to the nth station An respectively, and the controller unit 20n corresponding to the second station A2 outputs the second control signal to the field metering unit 302 in the second station A2, and the controller unit 20n corresponding to the nth station An outputs the second control signal to the field metering unit 30n in the nth station An.

[0045] This disclosure provides a gas pipeline burst protection system for gas stations, belonging to the field of long-distance pipeline safety monitoring technology. In existing technologies, for natural gas pipeline networks with extremely wide distribution distances, traditional DCS or PLC control systems face technical bottlenecks such as complex wiring and unstable signal transmission. This results in the dispatch center being unable to obtain real-time pipeline status information from each remote station, making it difficult to promptly detect and accurately locate burst accidents. Once a pipeline rupture occurs, rapid shut-off is impossible, easily leading to continuous gas leakage, causing not only resource waste and economic losses but also posing a serious threat to public safety. To solve these technical problems, this system innovatively constructs a hierarchical distributed control architecture. The system includes a station control unit, at least one controller unit, and corresponding field metering units. Each remote station is independently configured with a controller unit and a field metering unit, forming an autonomous local monitoring node. The field metering unit is responsible for real-time collection of various status parameters of the gas pipeline in its station area, including key process variables such as pressure, flow rate, and temperature. The controller unit serves as a local data processing and communication hub. The station control unit acts as the system's intelligent decision-making center, realizing centralized monitoring of the entire network's operating status. The system's working principle is based on a unique monitoring... The decision-making and execution mechanism involves the continuous collection of pipeline status information by the field metering units at each station. This information is then aggregated by the controller unit and sent to the station control unit. The station control unit incorporates an intelligent analysis algorithm. When it detects that the pipeline status information (especially pressure parameters) at a certain station is below a preset safety threshold, it immediately generates a first control signal and sends it to the corresponding station's controller unit. This controller unit then converts the signal into a second control signal, driving the actuator in the field metering unit to quickly shut off the valve, thus forming a complete emergency response closed loop. The core innovation of this system lies in its "centralized management, decentralized control" architecture, which ensures both the overall coordination of the system and the real-time performance of local control. By establishing an independent monitoring unit at each station, the system effectively overcomes the delay problem of long-distance signal transmission. By establishing standardized communication protocols and response mechanisms, it achieves collaborative protection across multiple stations. Compared with existing technologies, this system significantly improves the identification speed and handling efficiency of pipe burst accidents, transforming the traditional manual judgment, hierarchical reporting, and manual handling mode into a fully automated intelligent response system. This greatly reduces the risk of accident escalation, improves the level of automated management of pipeline network operation, and provides reliable technical support for long-distance natural gas transportation.

[0046] Example 2 like Figure 2As shown, the field metering unit 30 includes a temperature acquisition unit 31, a flow acquisition unit 32, a switch unit 33, and a pressure acquisition unit 34. The flow acquisition unit 32, pressure acquisition unit 34, switch unit 33, and temperature acquisition unit 31 are respectively installed on the gas distribution pipeline at the station. The flow acquisition unit 32 acquires the flow information of the gas distribution pipeline at the station, the pressure acquisition unit 34 acquires the pressure information of the gas distribution pipeline at the station, and the temperature acquisition unit 31 acquires the temperature information of the gas distribution pipeline at the station. The flow acquisition unit 32 sends the flow information to the controller unit 20, and the pressure acquisition unit 34 acquires the pressure information. The acquisition unit 34 sends pressure information to the controller unit 20, and the temperature acquisition unit 31 sends temperature information to the controller unit 20. Each controller unit 20 located at different stations sends the received flow information, pressure information, and temperature information of the gas pipeline to the station control unit 10 respectively. When the station control unit 10 receives that the flow information of the gas pipeline at a station is less than the preset flow information and / or the pressure information is less than the preset pressure information, it outputs a first control signal to the controller unit 20 corresponding to that station, and controls the controller unit 20 corresponding to that station to output a second control signal to control the switch unit to turn off.

[0047] like Figure 2 As shown, each site metering unit 30 includes a temperature acquisition unit 31, a flow acquisition unit 32, a switch unit 33, and a pressure acquisition unit 34. Temperature acquisition units 31, flow acquisition units 32, switch units 33, and pressure acquisition units 34 located at the same site are communicatively connected to the controller unit 20 located at that site. Controller units 20 located at different sites are communicatively connected to the station control unit 10. For example, the site metering unit 30 at the first site A1 includes a temperature acquisition unit 311, a flow acquisition unit 321, a switch unit 331, and a pressure acquisition unit 341. Temperature acquisition units 311, flow acquisition units 321, switch units 331, and pressure acquisition units 341 are communicatively connected to the controller unit 201. The site metering unit 30 at the second site A2... 2 includes a temperature acquisition unit 312, a flow acquisition unit 322, a switch unit 332, and a pressure acquisition unit 342. The temperature acquisition unit 312, flow acquisition unit 322, switch unit 332, and pressure acquisition unit 342 are respectively connected to the controller unit 202. ... The field metering unit 30n at the nth station An includes a temperature acquisition unit 31n, a flow acquisition unit 32n, a switch unit 33n, and a pressure acquisition unit 34n. The temperature acquisition unit 31n, flow acquisition unit 31n, switch unit 33n, and pressure acquisition unit 34n are respectively connected to the controller unit 20n. The controller unit 201 at the first station A1, the controller unit 202 at the second station A2, ... the controller unit 20n at the nth station An are respectively connected to the station control unit 10.

[0048] Specifically, temperature acquisition unit 31, flow acquisition unit 32, and pressure acquisition unit 34, located at different stations, acquire temperature, flow, and pressure information of the gas pipeline at different stations and send the acquired information to controller unit 20 located at the same station. Specifically, temperature acquisition unit 311 at the first station A1 acquires the temperature information of the gas pipeline at station A1 and sends it to controller unit 201 at station A1; flow acquisition unit 321 at station A1 acquires the flow information of the gas pipeline at station A1 and sends it to controller unit 201 at station A1; and pressure acquisition unit 34 at station A1 acquires the flow information of the gas pipeline at station A1 and sends it to controller unit 201 at station A1. 341 acquires the pressure information of the gas pipeline at the first station A1 and sends the pressure information of the gas pipeline at the first station A1 to the controller unit 201 set at the first station A1; 312, a temperature acquisition unit set at the second station A2, acquires the temperature information of the gas pipeline at the second station A2 and sends the temperature information of the gas pipeline at the second station A2 to the controller unit 202 set at the second station A2; 322, a flow acquisition unit set at the second station A2, acquires the flow information of the gas pipeline at the second station A2 and sends the flow information of the gas pipeline at the second station A2 to the controller unit 202 set at the second station A2; 342, a pressure acquisition unit set at the second station A2, acquires the pressure information of the gas pipeline at the first station A1 and sends the pressure information of the gas pipeline at the second station A2 to the controller unit 202 set at the second station A2; ...Temperature acquisition unit 31n at station n An acquires the temperature information of the gas pipeline at station n An and sends it to controller unit 20n at station n An. Flow acquisition unit 32n at station n An acquires the flow information of the gas pipeline at station n An and sends it to controller unit 20n at station n An. Pressure acquisition unit 34n at station n An acquires the pressure information of the gas pipeline at station n An and sends it to controller unit 20n at station n An. When controller units 20n at stations A1 to n An respectively acquire the temperature information of the gas pipeline at station n An... After receiving the temperature, flow rate, and pressure information of the corresponding gas pipeline at each station, the controller units 20 located at different stations will send the received gas pipeline temperature, flow rate, and pressure information from each station to the station control unit 10. Specifically, the controller unit 201 at the first station A1 will send the acquired gas pipeline temperature, flow rate, and pressure information from the first station A1 to the station control unit 10; the controller unit 202 at the second station A2 will send the acquired gas pipeline temperature, flow rate, and pressure information from the second station A2 to the station control unit 10; and so on, the controller unit 20n at the nth station An will send the acquired gas pipeline temperature, flow rate, and pressure information from the nth station An to the station control unit 10.

[0049] After receiving temperature, flow, and pressure information of gas pipelines at different stations, the station control unit 10 analyzes the relationship between the flow information and preset flow and / or pressure information at different stations. When the flow information and / or pressure information at at least one station are less than the preset flow and / or pressure information, the station control unit 10 outputs a first control signal to the controller unit 20 corresponding to that station. The first controller unit 20 then outputs a second control signal to the switch unit 33 to shut down the switch unit 33 at that station. For example, if a gas pipeline at the second station A2 experiences a rupture, the station control unit 10 will then... When a gas pipeline ruptures, some natural gas leaks, causing changes in the flow rate or pressure. Specifically, the flow rate or pressure at the second station A2 will decrease. The station control unit 10 receives a signal indicating that the flow rate at the second station A2 is less than the preset flow rate and / or the pressure is less than the preset pressure. In this case, the station control unit 10 outputs a first control signal to the controller unit 202 at the second station A2, which in turn outputs a second control signal to the switch unit 332 in the field metering unit 302, causing the switch unit 332 at the second station A2 to shut off, thus preventing further natural gas leakage.

[0050] This disclosure provides a natural gas pipeline pressure drop rate explosion-proof pipe detection technology system. Each site metering unit includes a temperature acquisition unit, a flow acquisition unit, a switch unit, and a pressure acquisition unit. The temperature, flow, and pressure acquisition units at different sites acquire the temperature, flow, and pressure information of the gas pipeline at that site and send this information to a controller unit located at the same site. Each controller unit at different sites sends the received gas pipeline temperature, flow, and pressure information to a station control unit. When the station control unit receives flow information and / or pressure information from a site that is less than a preset flow rate and / or pressure information that is less than a preset pressure, it outputs a first control signal to the corresponding controller unit. This controller unit then outputs a second control signal to the switch unit in the site metering unit, closing the switch and preventing gas leaks caused by a gas pipeline rupture at a site. This improves work efficiency and management level.

[0051] Example 3 like Figure 3 As shown, the gas pipeline burst protection system in the station also includes a flow calculation unit 40, which is communicatively connected to the station control unit 10. The flow calculation unit 40 calculates the standard flow information corresponding to the flow information based on the temperature information, pressure information and flow information.

[0052] Because the flow information collected by the flow acquisition unit 32 in the field metering unit 30 is different from the flow information under standard conditions during the natural gas distribution process, a flow calculation unit 40 is set up. The flow calculation unit 40 obtains the temperature information collected by the temperature acquisition unit, the pressure information collected by the pressure acquisition unit, and the flow information collected by the flow acquisition unit from the station control unit 10 to calculate the standard flow information corresponding to the flow information at each station.

[0053] Optional, see below Figure 3 The gas pipeline burst protection system at the station also includes an early warning unit. The early warning unit 50 is connected to the station control unit 10 and is used to output an early warning signal when the flow information is less than the preset flow information and / or the pressure information is greater than the preset pressure information.

[0054] By setting up an early warning unit 50, an early warning signal is output when the flow rate is less than the preset flow rate and / or the pressure is less than the preset pressure. This ensures that operators can promptly obtain warning information when there are abnormalities in the gas distribution pipelines at different stations, thus ensuring the safe and reliable operation of the gas distribution pipelines at different stations.

[0055] Optionally, the flow acquisition unit may include a flow meter.

[0056] For example, the flow acquisition unit can be set to include a flow meter. Specifically, the flow meter can be a liquid flow meter or a differential pressure flow meter. This utility model embodiment does not limit the specific type of flow meter. When using a liquid flow meter to obtain the flow information of the gas pipeline, the liquid flow meter has energy-saving characteristics compared to the differential pressure flow meter because it has no moving parts, reliable operation, good performance, long service life, does not directly contact the sensor when measuring the fluid being measured, has stable performance, and less pressure loss.

[0057] Optionally, the switching unit includes an electric ball valve.

[0058] For example, the switching unit can be configured to include an electric ball valve. Specifically, the electric ball valve includes an electric actuator and a valve. By using electrical energy as power, the electric actuator is activated. The electric actuator drives the ball valve stem to rotate 0-90 degrees to realize the valve's opening and closing action, thereby achieving the purpose of opening or regulating the gas pipeline. The electric ball valve is generally driven by a motor. The opening degree of the electric valve can be controlled, with states including open, closed, and half-open / half-closed, which can control the flow rate of the medium in the gas pipeline.

[0059] Optionally, the pressure acquisition unit includes a pressure sensor.

[0060] The pressure acquisition unit includes a pressure sensor, which acquires pressure information from the gas pipeline. The pressure sensor can be a capacitive pressure sensor, a silicon piezoresistive pressure sensor, or other pressure sensors. This embodiment does not specifically limit the type of pressure sensor.

[0061] Optionally, the temperature acquisition unit includes a temperature sensor.

[0062] The temperature acquisition unit includes a temperature sensor, which acquires temperature information of the gas pipeline. The temperature sensor can be a resistance temperature detector, a thermistor, a sensitive element, or a thermocouple, etc. This embodiment does not specifically limit the type of temperature sensor.

[0063] Optionally, the controller unit 20 is housed within the containment space of the explosion-proof control cabinet.

[0064] By setting the controller unit 20 to be fixedly installed in the containment space of the explosion-proof control cabinet, the high voltage generated by lightning strikes (direct lightning strikes, induced lightning, etc.) is prevented from entering the interface of the controller unit 20.

[0065] Specifically, an ammeter is connected in series with the live wire inside the explosion-proof control cabinet to detect the line current, and a voltmeter is connected in parallel with the line to detect the line voltage. Indicator lights are installed on both the 220V and 24V power supply circuits to indicate whether the circuit is operating normally. In addition, the explosion-proof control cabinet is equipped with a surge protector. One end of the surge protector is grounded, and the other end is connected in parallel to the 220VAC power supply. The surge protector model is P-FL-385 / 40*2P, with a protection class of B2 and a maximum continuous voltage of 440V. The surge protector can prevent high-voltage signals from flooding into the controller unit 20 when analog or switch signals collected by the field metering unit 30 at different sites are input.

[0066] Optional, see below Figure 3 The gas pipeline burst protection system at the station also includes a display unit 60, which is communicatively connected to the station control unit 10 and is used to display flow information, pressure information, temperature information, and status information of the switch unit.

[0067] The burst pipe protection system also includes a display unit 60, which displays the liquid level, pressure, and temperature information of each station in the station control unit 10, as well as the status information of the switch units. For example, when a gas pipeline at the second station A2 bursts, some natural gas leaks, causing changes in the flow rate or pressure of the gas pipeline. That is, the flow rate or pressure of the gas pipeline at the second station A2 will decrease. The display unit 60 obtains and displays the flow rate and pressure information of the second station A2 from the station control unit 10. Station operators can determine whether the current station is in operation or the cumulative gas flow loss of the current station by analyzing the flow rate, pressure information, and status information of the switch units at the second station A2.

[0068] Although embodiments of the present invention have been shown and described, it will be understood by those skilled in the art that various changes, modifications, substitutions and alterations can be made to these embodiments without departing from the principles and spirit of the present invention, the scope of which is defined by the appended claims and their equivalents.

Claims

1. A system device for detecting the pressure drop rate of a natural gas pipeline explosion-proof pipe, characterized in that: It includes a station control unit, a controller unit, and a field metering unit, with one controller unit and one field metering unit installed at each station; The field metering unit located at the same station is communicatively connected to the controller unit, and each controller unit located at a different station is communicatively connected to the station control unit. Each of the field metering units located at different stations acquires the status information of the gas pipeline at different stations and sends the status information to the controller unit located at the same station as the field metering unit. Each of the controller units located at different stations sends the received status information of the gas pipeline at each station to the station control unit. When the station control unit receives a status information of a gas pipeline at a station that is less than a preset status information, the station control unit outputs a first control signal to the controller unit corresponding to that station, and controls the controller unit corresponding to that station to output a second control signal to the field metering unit.

2. The natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device according to claim 1, characterized in that: The field metering unit includes a temperature acquisition unit, a flow acquisition unit, a switch unit, and a pressure acquisition unit; The flow acquisition unit, the pressure acquisition unit, the switch unit, and the temperature acquisition unit are respectively installed on the gas distribution pipeline at the station; The flow acquisition unit obtains the flow information of the gas distribution pipeline at the station; The pressure acquisition unit obtains pressure information from the gas distribution pipeline at the station. The temperature acquisition unit obtains the temperature information of the gas distribution pipeline at the station.

3. The natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device according to claim 2, characterized in that: The flow acquisition unit sends the flow information to the controller unit, the pressure acquisition unit sends the pressure information to the controller unit, the temperature acquisition unit sends the temperature information to the controller unit, and each controller unit located at different stations sends the received flow, pressure and temperature information of the gas pipeline to the station control unit respectively.

4. The natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device according to claim 3, characterized in that: When the station control unit receives information that the flow rate of the gas pipeline at a station is less than a preset flow rate and / or the pressure is less than a preset pressure, it outputs a first control signal to the controller unit corresponding to that station, and controls the controller unit corresponding to that station to output a second control signal to control the switch unit to turn off.

5. The natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device according to claim 4, characterized in that: The field metering unit also includes a flow calculation unit, which is communicatively connected to the station control unit. The flow calculation unit calculates the standard flow information corresponding to the flow information based on the temperature information, the pressure information, and the flow information. The field metering unit also includes an early warning unit, which is communicatively connected to the station control unit and is used to output an early warning signal when the flow information is less than a preset flow information and / or the pressure information is less than a preset pressure information.

6. The natural gas pipeline pressure drop rate explosion-proof pipe detection technology system device according to claim 5, characterized in that: The field metering unit also includes a display unit, which is communicatively connected to the station control unit and is used to display the flow rate information, the pressure information, the temperature information, and the status information of the switch unit.

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