Natural gas pipeline flow measurement method and system based on ultrasonic measurement

Abstract

The invention discloses a natural gas pipeline flow measurement method and system based on ultrasonic measurement, and relates to the technical field of natural gas pipeline flow measurement. Processing the acquired data based on the first compensation; and monitoring and managing data transmission. According to the natural gas pipeline flow measurement method based on ultrasonic measurement, the upstream straight pipe section and the downstream straight pipe section are installed, and the flow adjuster is properly adjusted, so that the measurement stability is ensured. By combining the instantaneous flow velocity, pressure and temperature data, the beneficial effect of monitoring the dynamic flow in real time is achieved, and the measurement result has higher adaptability and real-time performance. Multi-parameter compensation and data processing enable data processing to be intelligent, and it is ensured that an output result has high precision. According to the method, better effects are achieved in the aspects of improving application adaptability and safety and reducing the influence of the environment on equipment.

Description

Technical Field

[0001] The present invention relates to the technical field of natural gas pipeline flow measurement, and in particular to a natural gas pipeline flow measurement method and system based on ultrasonic measurement. Background Art

[0002] With the continuous growth of natural gas demand, the safe and efficient transportation of natural gas pipelines has become an important research direction. In this process, the accurate measurement of natural gas flow is particularly critical. Currently, the widely used flow measurement technologies include vortex flowmeters, turbine flowmeters and mass flowmeters, which perform well in situations where the gas flow rate and pressure environment are relatively stable. However, limited by measurement accuracy and response speed, these traditional technologies have certain shortcomings when dealing with complex pipeline environments and rapidly changing flow conditions. In recent years, ultrasonic flow measurement technology has attracted widespread attention due to its characteristics of no mechanical parts, high pressure resistance and low maintenance. Ultrasonic flow meters, especially ultrasonic measurement methods based on the time difference method, can accurately capture gas flow changes and show high measurement accuracy and stability in large-diameter and long-distance natural gas pipelines.

[0003] Although ultrasonic flow measurement technology has made significant progress in natural gas pipeline applications, the current technical solutions still have the following shortcomings. First, most existing high-precision ultrasonic flowmeters rely on imported equipment, which is costly and complex to maintain, affecting the economic feasibility of widespread promotion. Secondly, traditional measurement systems often suffer from data distortion when the flow rate changes drastically or the pressure is unstable, and cannot provide accurate real-time monitoring information. In addition, the existing ultrasonic flowmeter system lacks an effective multi-parameter compensation mechanism, and it is difficult to eliminate the measurement errors caused by temperature and pressure fluctuations in a dynamic environment. Especially in the process of natural gas transportation, the temperature and pressure change frequently, and the existing system lacks pertinence in real-time compensation, resulting in data accuracy that is difficult to meet actual needs. In contrast, the present invention significantly improves the accuracy and real-time performance of the data by systematically integrating ultrasonic flowmeters, flow computers, temperature and pressure transmitters, and combining multi-parameter compensation technology. At the same time, the use of an autonomous and controllable SCADA monitoring system and diagnostic software not only reduces the dependence on imported equipment, but also improves the security of the system and the reliability of data storage. Through real-time monitoring and diagnostic functions, the present invention can achieve fault warning and maintenance support, significantly improve the stability and reliability of the system, and solve the pain point that the existing technology is difficult to measure stably in a complex environment. Summary of the invention

[0004] In view of the above-mentioned problems, the present invention is proposed.

[0005] Therefore, the technical problem solved by the present invention is: the existing natural gas flow measurement method has problems such as dependence on imported equipment, data distortion and insufficient real-time compensation, and how to achieve high-precision, safe and real-time natural gas flow measurement in a dynamic environment.

[0006] To solve the above technical problems, the present invention provides the following technical solutions: a natural gas pipeline flow measurement method based on ultrasonic measurement, comprising initializing a first device to set environmental conditions; processing collected data based on a first compensation; and monitoring and managing data transmission.

[0007] As a preferred solution of the natural gas pipeline flow measurement method based on ultrasonic measurement described in the present invention, wherein: the initialization includes configuring initial parameters.

[0008] As a preferred solution of the natural gas pipeline flow measurement method based on ultrasonic measurement described in the present invention, wherein: the setting of environmental conditions includes installing a straight pipe section and setting a regulator.

[0009] As a preferred solution of the natural gas pipeline flow measurement method based on ultrasonic measurement described in the present invention, wherein: the collected data is processed based on the first compensation, including obtaining the flow velocity, outputting the instantaneous value of the flow through the time difference method; and collecting pressure and temperature data.

[0010] As a preferred solution of the natural gas pipeline flow measurement method based on ultrasonic measurement described in the present invention, wherein: the processing of the collected data based on the first compensation includes compensating the data using the first compensation.

[0011] As a preferred solution of the natural gas pipeline flow measurement method based on ultrasonic measurement described in the present invention, wherein: the monitoring management data transmission includes transmitting the data to a central control system.

[0012] As a preferred solution of the natural gas pipeline flow measurement method based on ultrasonic measurement described in the present invention, the monitoring management data transmission includes real-time detection of system health status, identification of abnormalities and alarm, and generation of diagnostic reports to support preventive maintenance.

[0013] Another object of the present invention is to provide a natural gas pipeline flow measurement system based on ultrasonic measurement, which can collect data and process it based on the first compensation, thereby solving the problems of data distortion and insufficient real-time compensation in the current natural gas flow measurement method.

[0014] As a preferred solution of the natural gas pipeline flow measurement system based on ultrasonic measurement described in the present invention, it includes: a measurement preparation and initialization module, a data acquisition and processing module, and a monitoring and data management module; the path planning module is used to ensure the startup of the measurement system; the data acquisition and processing module is used to acquire and process data in the natural gas pipeline in real time and output the flow; the monitoring and data management module is used to support maintenance and data analysis through real-time monitoring and data management.

[0015] A computer device comprises a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to implement the steps of a natural gas pipeline flow measurement method based on ultrasonic measurement.

[0016] A computer-readable storage medium stores a computer program, which, when executed by a processor, implements the steps of a natural gas pipeline flow measurement method based on ultrasonic measurement.

[0017] Beneficial effects of the present invention: The natural gas pipeline flow measurement method based on ultrasonic measurement provided by the present invention makes the gas flow tend to be uniform by installing upstream and downstream straight pipe sections and appropriately adjusting the flow regulator, thereby reducing the disturbance effect in the airflow, thereby ensuring the stability of the measurement. By combining instantaneous flow velocity, pressure and temperature data, the beneficial effect of real-time monitoring of flow dynamics is achieved, so that the measurement results have stronger adaptability and real-time performance. Multi-parameter compensation and data processing make data processing intelligent and ensure that the output results have high precision. Finally, through multi-parameter compensation, the beneficial effect of eliminating the influence of the external environment and outputting stable flow data is achieved. Through remote monitoring and management functions, the beneficial effect of improving system controllability and monitoring efficiency is achieved, which is convenient for timely response to system abnormalities. The present invention has achieved better results in improving application adaptability, safety and reducing the impact of the environment on equipment. BRIEF DESCRIPTION OF THE DRAWINGS

[0018] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings required for use in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other accompanying drawings can be obtained based on these accompanying drawings without paying creative work.

[0019] Figure 1 An overall flow chart of a natural gas pipeline flow measurement method based on ultrasonic measurement provided by the first embodiment of the present invention.

[0020] Figure 2 A structural diagram of a natural gas pipeline flow measurement method based on ultrasonic measurement provided in the first embodiment of the present invention.

[0021] Figure 3 An overall flow chart of a natural gas pipeline flow measurement system based on ultrasonic measurement provided in the third embodiment of the present invention. DETAILED DESCRIPTION

[0022] In order to make the above-mentioned purposes, features and advantages of the present invention more obvious and easy to understand, the specific implementation methods of the present invention are described in detail below in conjunction with the drawings of the specification. Obviously, the described embodiments are part of the embodiments of the present invention, but not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary persons in the art without creative work should fall within the scope of protection of the present invention.

[0023] Example 1, reference Figure 1-Figure 2 , as an embodiment of the present invention, provides a natural gas pipeline flow measurement method based on ultrasonic measurement, comprising:

[0024] S1: Initialize the first device to set environmental conditions.

[0025] Furthermore, the first device can be multiple, such as gas ultrasonic flowmeter, flow computer, pressure transmitter, temperature transmitter, vortex flowmeter, PLC (programmable logic controller) system, strain gauge pressure sensor, thermal resistance temperature sensor, etc. In this embodiment, the system initialization is used to ensure that the ultrasonic flowmeter, flow computer, pressure and temperature transmitter of the system communicate normally with the SCADA system. The initial parameters are configured, and the upper computer software is used to debug and preliminarily calibrate the equipment to ensure that the equipment starts measuring in the preset state.

[0026] It should be noted that in another feasible embodiment, the first device adopts a vortex flowmeter, a PLC (programmable logic controller) system, a strain gauge pressure sensor, and a thermal resistor temperature sensor, including: Vortex flowmeter: suitable for medium and high flow rate gas flow measurement, based on the frequency generated by the vortex being proportional to the flow rate. Suitable for the measurement of impurity-free gas, but sensitive to vibration. PLC (programmable logic controller) system: can realize data acquisition, processing and control through programming, has versatility, and is suitable for integration into automation systems, but may not be as good as dedicated flow computers in terms of high-precision calculations. Strain gauge pressure sensor: based on strain gauges to measure pressure changes, suitable for large-range pressure measurement, and can achieve higher pressure monitoring accuracy at low cost. Thermal resistor temperature sensor (RTD, Pt100, etc.): commonly used in industrial temperature measurement, with good linearity and stability, especially suitable for environments requiring precise temperature measurement.

[0027] Furthermore, the environmental conditions are set, and upstream and downstream straight pipe sections are installed to reduce air flow disturbances and ensure the stability of the measurement. By adjusting the flow regulator and other devices, the gas flow is made uniform to ensure the accuracy of subsequent measurements.

[0028] S2: The collected data is processed based on the first compensation.

[0029] Furthermore, real-time data collection uses a gas ultrasonic flow meter to obtain the flow rate and calculates the instantaneous value of the flow rate by the time difference method. The pressure and temperature data in the pipeline are collected in real time through pressure and temperature transmitters to provide compensation parameters for the measurement results.

[0030] It should be noted that the first compensation can be of various types, such as multi-parameter compensation, adaptive filtering compensation, environmental sensor array compensation, etc. In this embodiment, the flow computer is used to combine temperature and pressure data with flow rate data to compensate the flow data. The real-time data is analyzed and processed by the built-in calculation algorithm to output high-precision flow data.

[0031] It should be noted that in another feasible embodiment, the first compensation adopts adaptive filtering compensation and environmental sensor array compensation, including: the adaptive filter can adjust the system output in real time to reduce the measurement error caused by the external environment or the internal changes of the system. Common adaptive filtering algorithms include Kalman filtering and adaptive mean filtering. Kalman filtering can combine a variety of real-time measurement data to predict and correct the flow data deviation, which is suitable for dynamically changing environments. Adaptive filters are used in environments with high real-time performance, especially in occasions where temperature and pressure change frequently, which helps to reduce instantaneous data fluctuations. Environmental sensor array compensation forms a sensor array by installing multiple environmental sensors (such as temperature, humidity, air pressure sensors, etc.), collecting multi-point data in real time, and comprehensively calculating the impact of each position on the flow, thereby achieving all-round compensation. Through more detailed environmental data collection, more environmental changes on the scene can be reflected and the accuracy of measurement can be improved. Environmental sensor array compensation is suitable for scenarios where flow measurement is required in large areas or multiple sections of pipelines.

[0032] S3: Monitor and manage data transmission.

[0033] Furthermore, data transmission and monitoring can transmit flow, temperature and pressure data to the central control system through the SCADA system to achieve remote real-time monitoring. The flow data can be displayed and managed by the host computer software, and users can monitor the system operation status on the interface.

[0034] It should be noted that for fault diagnosis and data storage, the diagnostic software detects the health status of the system in real time, identifies abnormalities and issues alarms, and generates diagnostic reports to support preventive maintenance. The system stores data such as flow, pressure, and temperature in a local or central control system, and has a power-off protection function to ensure the security and integrity of the data.

[0035] Furthermore, the topology of the natural gas pipeline flow measurement system of the pressure regulating station is designed, and the system is built according to the topology. The system includes a gas ultrasonic flow meter, a flow computer, a pressure transmitter, a temperature transmitter, upstream and downstream straight pipe sections, a flow regulator, a metering system control cabinet, a host computer software and diagnostic software:

[0036] (1) Gas ultrasonic flow meter:

[0037] Function: Used to measure the flow of natural gas. Ultrasonic technology can achieve high-precision and low-pressure loss flow measurement.

[0038] Advantages: No mechanical moving parts, simple maintenance, suitable for large pipe diameter and high pressure occasions.

[0039] (2) Flow computer:

[0040] Function: Receive the signal from the gas ultrasonic flowmeter, process and calculate the data, and output the flow data.

[0041] Advantages: High-performance processor, supports multiple computing algorithms, and can process large amounts of data in real time.

[0042] (3) Pressure transmitter:

[0043] Function: Measure the pressure in the pipeline and transmit the pressure signal to the flow computer.

[0044] Advantages: high precision, fast response, and able to adapt to complex working environments.

[0045] (4) Temperature transmitter:

[0046] Function: Measure the temperature in the pipeline and transmit the temperature signal to the flow computer.

[0047] Advantages: high precision, good stability, and able to operate over a wide temperature range.

[0048] (6) Upstream straight pipe section:

[0049] Function: Ensure the stability of gas flow and reduce the impact of flow disturbance on measurement.

[0050] Advantages: Reasonable design, can effectively reduce flow disturbance.

[0051] (7) Downstream straight pipe section:

[0052] Function: Ensure the stability of gas flow and reduce the impact of flow disturbance on measurement.

[0053] Advantages: Reasonable design, can effectively reduce flow disturbance.

[0054] (8)SCADA monitoring system:

[0055] Function: Centrally monitor and manage the entire flow measurement system, and display and record flow data in real time.

[0056] Advantages: powerful functions, user-friendly interface, support for remote monitoring and data analysis.

[0057] (9) Computer and diagnostic software:

[0058] Function: Used for system diagnosis and maintenance, capable of detecting and troubleshooting system failures.

[0059] Advantages: High degree of intelligence, able to automatically generate diagnostic reports.

[0060] (10) Host computer software:

[0061] Function: To interact with flow computers and SCADA systems and provide a user-friendly operation interface.

[0062] Advantages: comprehensive functions, easy operation, support for various data analysis and report generation.

[0063] Connections between system modules:

[0064] The gas ultrasonic flow meter is connected to the flow computer through a signal line to transmit flow data in real time.

[0065] The pressure transmitter and temperature transmitter measure the pressure and temperature in the pipeline respectively and transmit the signals to the flow computer.

[0066] The flow computer receives signals from the gas ultrasonic flow meter, pressure transmitter and temperature transmitter, performs data processing and calculation, and outputs flow data.

[0067] The upstream straight pipe section and the downstream straight pipe section ensure the stability of gas flow and reduce the influence of flow disturbance on measurement.

[0068] The SCADA monitoring system centrally monitors and manages the entire flow measurement system, and displays and records flow data in real time.

[0069] Computers and diagnostic software are used for system diagnosis and maintenance, and can detect and eliminate system failures.

[0070] The host computer software exchanges data with the flow computer and SCADA system, providing a user-friendly operation interface.

[0071] The system hardware includes:

[0072] (1) Gas Ultrasonic Flow Meter

[0073] 1. Measurement principle: time difference method

[0074] 2. Measuring range: 0.1m / s~30m / s

[0075] 3. Range ratio: ≥80:1

[0076] 4. Channel layout type: ≥4 channels, opposite channel layout

[0077] 5. Explosion-proof and protection level: not less than ExdbⅡBT6, not less than IP66

[0078] 6. Flow meter measurement performance requirements:

[0079] Before adjusting any coefficient, the flow measurement performance of the gas ultrasonic flow meter should meet the following requirements:

[0080] Resolution: 0.001m / s;

[0081] Speed ​​sampling interval: ≤0.1s;

[0082] Zero flow reading: each channel ≤6mm / s;

[0083] The maximum sound speed difference between each channel: 0.5m / s;

[0084] After the flow meter is calibrated, the flow measurement accuracy level must reach the 0.5 level requirement, that is:

[0085] Maximum allowable error: ±0.5%, qt≤qi≤qmax;

[0086] ±1.0%,qmin≤qi<qt;

[0087] Flow measurement repeatability: ≤0.1%, qt≤qi≤qmax;

[0088] ≤0.2%,qmin≤qi<qt;

[0089] The flow meter's boundary flow rate qt≤0.1qmax;

[0090] Maximum peak-to-peak error: not greater than the maximum allowable error.

[0091] 7. Overload capacity: ≥1.2Qmax

[0092] 8. Power supply: 24VDC

[0093] 9. Output signal: 3 RS485, 1 Ethernet, 1 4~20mA (support HART), etc.

[0094] (2) Flow Computer

[0095] 1. The integrated flow computer should be able to select and lock the measurement standard through simple configuration or options. During normal calculation, it should not be affected by other measurement standards;

[0096] 2. The integrated flow computer should be able to set standard reference conditions;

[0097] 3. The integrated flow computer should have self-diagnosis function and be able to store diagnostic results and diagnostic alarms;

[0098] 4. The system hardware and software configuration of the integrated flow computer should be provided, and the communication technology files and data transmission format should be provided to meet the communication requirements with the upper computer control system;

[0099] 5. The calculation method of natural gas compression factor of integrated flow computer shall meet the requirements of GB / T 17747 or AGANO.8 standard;

[0100] 6. The storage device of the integrated flow computer should be able to store at least 365 days of accumulated flow, pressure, temperature, alarm and other data;

[0101] 7. The integrated flow computer should have power-off protection function;

[0102] 8. The serial port signal provided by the integrated flow computer should comply with the standard Modbus communication technical documents;

[0103] 9. The input and output signal channels provided by the integrated flow computer are at least:

[0104] 1) Analog input: 2 channels, standard 4mA~20mADC, support HART;

[0105] 2) Digital output: 2 channels;

[0106] 3) Analog output: 2 channels;

[0107] 4) Frequency output: 2 channels;

[0108] 5) Communication interface: 3-way, RS-485 interface;

[0109] 6) Communication interface: 1-way, Ethernet port.

[0110] (3) Pressure compensation instrument

[0111] 1. The pressure transmitter should be an absolute pressure transmitter, the maximum allowable error should be better than ±0.075%, and the output signal should be 4mA~20mADC (two-wire system with HART communication protocol);

[0112] 2. The absolute pressure transmitter should have good temperature characteristics. The impact of changes in ambient temperature on its zero point and range should be better than: ±(0.025% of the upper limit of the range + 0.125% of the range) / 28°C under the condition of the maximum range;

[0113] (4) Temperature compensation instrument

[0114] 1. The metering system should use Pt100 vibration-resistant thermal resistance temperature transmitter as the temperature compensation instrument for the metering system temperature compensation. The Pt100 thermal resistance should be a 4-wire system, and its technical performance should comply with Class A (IEC 60751). The maximum allowable system error of the Pt100 thermal resistance and its temperature transmitter should be better than ±0.15℃. The transmitter output signal should be 4mA~20mADC (two-wire system, with HART communication protocol);

[0115] 2. For the protective sleeve of the temperature compensation instrument, when the measuring pipeline is ≤DN300, the protective sleeve should be inserted into the pipeline perpendicular to the axis at a position approximately 1 / 2 to 1 / 3 of the nominal inner diameter of the pipeline. When the measuring pipeline is >DN300, the protective sleeve should be within the range of 100mm±25mm.

[0116] (5) Supporting facilities

[0117] 1. Overall requirements for metering straight pipe sections

[0118] 1) The interface diameter of the flow meter body should be the same as the inner diameter of the straight pipe section with flanges immediately upstream and downstream. The difference in inner diameter between them should be within ±1% and not exceed 3mm;

[0119] 2) When designing the metering straight pipe section, the installation position of the flow meter, the form of the upstream resistance, and the relative installation position of the pressure regulating valve should be comprehensively considered;

[0120] 3) The length of the straight pipe section shall comply with the requirements of GB / T18604;

[0121] 4) If the flow meter requires bidirectional metering function, both ends of the flow meter should be considered as upstream, and the bidirectional straight pipe section configuration should be set according to the upstream setting;

[0122] 5) The temperature sampling hole of the unidirectional flow meter should be located between 2D and 5D from the downstream flange end face of the flow meter, and the temperature sampling hole of the bidirectional flow meter should be located at 5D from the flange end face of one end of the flow meter.

[0123] 2. Overall requirements for flow conditioners

[0124] 1) The flow regulator adopts flange clamping and fixing method. The ring clamping steel plate is clamped by two convex flanges. The contact surface of the ring clamping steel plate is the same as the sealing surface of the convex flange;

[0125] 2) It is recommended to use a low-noise, stainless steel plate-hole flange clamp flow regulator;

[0126] 3) The type of flow regulator should be selected based on the changes in working conditions, fluid conditions, and flow meter characteristics;

[0127] 4) The noise generated by the flow conditioner should not affect the normal operation and accuracy of the flow meter;

[0128] 5) The installation position of the flow conditioner should be 10D upstream of the flow meter. The length of the flow conditioner is not included in the length of the straight pipe section.

[0129] 6) The flow regulator type should match the flow meter.

[0130] 3. System Functions

[0131] The natural gas flow measurement system based on safety, autonomy and controllability realizes the following functions:

[0132] 1. High-precision flow measurement:

[0133] 2. Obtain high-precision natural gas flow data through the gas ultrasonic flow meter to ensure the accuracy of measurement.

[0134] Real-time data processing and analysis:

[0135] 3. Use flow computers to process data collected from various sensors in real time, including flow, pressure and temperature, for precise calculation and analysis.

[0136] 4. Multi-parameter monitoring:

[0137] 5. The system integrates pressure transmitter and temperature transmitter, which can monitor the pressure and temperature in the pipeline at the same time, so as to compensate for flow changes and improve the reliability of measurement.

[0138] 6. Data storage and transmission:

[0139] It supports real-time storage of data and can transmit it to the central control system or SCADA monitoring system via wireless or wired network for subsequent analysis and management.

[0140] 7. Remote monitoring and control:

[0141] Through the SCADA system, the above measurement data and system status can be monitored and managed remotely in real time, realizing remote operation of the flow measurement system.

[0142] 8. Diagnosis and maintenance support:

[0143] Equipped with intelligent diagnostic software, it supports real-time monitoring of system health status, can automatically detect system failures and generate diagnostic reports, and supports preventive maintenance.

[0144] 9. Safe, autonomous and controllable:

[0145] The system design has strengthened independent control capabilities, adopted domestically produced software and hardware, reduced dependence on imported equipment, and improved system security and independent controllability.

[0146] Energy Optimization and Sustainability:

[0147] 10. Optimize system design to reduce energy consumption and improve system sustainability and economy.

[0148] Through these functions, the system can provide a comprehensive, accurate and reliable solution for natural gas flow measurement, meeting the needs of modern energy management for efficient metering and monitoring.

[0149] like Figure 2 It is a structural diagram of the present invention, wherein 1 is a gas ultrasonic flow meter, 2 is a flow computer, 3 is a pressure transmitter, 4 is a temperature transmitter, 5 is an upstream straight pipe section, 6 is a downstream straight pipe section, 7 is a flow regulator, 8 is a metering system control cabinet, and 9 is a host computer software and diagnostic software.

[0150] Example 2, an embodiment of the present invention, provides a natural gas pipeline flow measurement method based on ultrasonic measurement. In order to verify the beneficial effects of the present invention, scientific demonstration is carried out through economic benefit calculation and simulation experiments.

[0151] First, the goal of this test is to evaluate the performance of a natural gas pipeline flow measurement method based on ultrasonic measurement under different operating conditions to verify the innovation of the invention in terms of accuracy and stability. The test was conducted in a natural gas transmission pipeline system and involved real-time multi-parameter acquisition, compensation processing and monitoring. The specific steps include the following:

[0152] After the system is installed, it is initialized to ensure the normal operation of the gas ultrasonic flowmeter, flow computer, pressure transmitter and temperature transmitter. The equipment communicates through the SCADA system to complete the initial parameter configuration and host computer debugging. After the first calibration verifies the responsiveness of the flowmeter and sensor, confirm that the equipment is in the preset state. According to the measurement requirements, the upstream and downstream straight pipe sections are installed to reduce the disturbance of the airflow. The flow conditioner is used to control the airflow so that the fluid reaches a uniform state, ensure the stability of the gas flow, and provide a reliable environmental basis for subsequent measurements. The system starts to collect data, uses the ultrasonic flowmeter to obtain the real-time flow rate, and calculates the instantaneous flow value by the time difference method. The pressure and temperature transmitters collect real-time data respectively as flow data compensation parameters. The flow computer combines the pressure, temperature and flow rate data, and processes them through the built-in algorithm to output high-precision compensated flow data. During the test, the flow, temperature and pressure data are transmitted to the central control system through the SCADA system to realize remote real-time monitoring, and the operator can view the data at any time. The test also uses diagnostic software to detect the health status of the system, generate data reports, and store flow and environmental parameters to ensure data integrity.

[0153] Table 1 Experimental data table

[0154]

[0155]

[0156] From the test data, the present invention can operate stably under different flow rates, pressures and temperatures. Through the changes in flow rate, pressure and temperature before and after adjustment, it is observed that there is consistency between the instantaneous flow rate and the compensated flow rate, indicating that the compensation algorithm shows high accuracy under changes in multiple environmental parameters. For example, when the flow rate after state adjustment increases from 1.2m / s to 2.5m / s, the flow change after compensation is relatively stable, indicating that the measurement system can maintain high accuracy through multi-parameter compensation under different environments.

[0157] In abnormal state 1, the system self-diagnoses and detects environmental anomalies and issues an alarm. The data transmission delay increases to 60ms, indicating that the system has monitoring and response functions and supports preventive maintenance. In the post-recovery state, the flow data gradually returns to stability. Through multi-parameter compensation, the final compensated flow only deviates by 0.02m 3 / s, showing the robustness of the compensation algorithm.

[0158] Compared with traditional flow meters, the present invention achieves more stable flow output through ultrasonic time difference method and multi-parameter compensation, reducing the impact of temperature and pressure changes on flow data. Through intelligent diagnosis and data transmission, the system demonstrates innovation in flow monitoring and data management, especially in reducing detection and response delays, achieving fast and accurate data response effects.

[0159] Example 3, reference Figure 3 , which is an embodiment of the present invention, provides a natural gas pipeline flow measurement system based on ultrasonic measurement, including a measurement preparation and initialization module, a data acquisition and processing module, and a monitoring and data management module.

[0160] The path planning module is used to ensure the startup of the measurement system, the data acquisition and processing module is used to acquire and process data in the natural gas pipeline in real time and output flow, and the monitoring and data management module is used to support maintenance and data analysis through real-time monitoring and data management.

[0161] If the function is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention, or the part that contributes to the prior art, or the part of the technical solution, can be embodied in the form of a software product. The computer software product is stored in a storage medium, including several instructions for a computer device (which can be a personal computer, server, or network device, etc.) to perform all or part of the steps of the methods of each embodiment of the present invention. The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), disk or optical disk, etc. Various media that can store program codes.

[0162] The logic and / or steps represented in the flowchart or otherwise described herein, for example, can be considered as an ordered list of executable instructions for implementing logical functions, and can be embodied in any computer-readable medium for use by an instruction execution system, device or apparatus (such as a computer-based system, a system including a processor, or other system that can fetch instructions from an instruction execution system, device or apparatus and execute instructions), or in conjunction with such instruction execution systems, devices or apparatuses. For the purposes of this specification, "computer-readable medium" can be any device that can contain, store, communicate, propagate or transmit a program for use by an instruction execution system, device or apparatus, or in conjunction with such instruction execution systems, devices or apparatuses.

[0163] More specific examples of computer-readable media (a non-exhaustive list) include the following: an electrical connection with one or more wires (electronic device), a portable computer disk case (magnetic device), a random access memory (RAM), a read-only memory (ROM), an erasable and programmable read-only memory (EPROM or flash memory), an optical fiber device, and a portable compact disk read-only memory (CDROM). In addition, the computer-readable medium may even be a paper or other suitable medium on which the program is printed, since the program may be obtained electronically, for example, by optically scanning the paper or other medium, followed by editing, deciphering, or processing in another suitable manner as necessary, and then stored in a computer memory.

[0164] It should be understood that the various parts of the present invention can be implemented by hardware, software, firmware or a combination thereof. In the above-mentioned embodiments, multiple steps or methods can be implemented by software or firmware stored in a memory and executed by a suitable instruction execution system. For example, if implemented by hardware, as in another embodiment, it can be implemented by any one of the following technologies known in the art or their combination: a discrete logic circuit having a logic gate circuit for implementing a logic function for a data signal, a dedicated integrated circuit having a suitable combination of logic gate circuits, a programmable gate array (PGA), a field programmable gate array (FPGA), etc. It should be noted that the above embodiments are only used to illustrate the technical solution of the present invention and are not limited. Although the present invention is described in detail with reference to the preferred embodiments, it should be understood by those skilled in the art that the technical solution of the present invention can be modified or replaced by equivalents without departing from the spirit and scope of the technical solution of the present invention, which should be included in the scope of the claims of the present invention.

[0165] It should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention rather than to limit it. Although the present invention has been described in detail with reference to the preferred embodiments, those skilled in the art should understand that the technical solutions of the present invention may be modified or replaced by equivalents without departing from the spirit and scope of the technical solutions of the present invention, which should all be included in the scope of the claims of the present invention.

Claims

1. A natural gas pipeline flow measurement method based on ultrasonic measurement, characterized in that: include: Initialize the first device to set environmental conditions; The collected data is processed based on the first compensation; Monitor and manage data transmission.

2. The natural gas pipeline flow measurement method based on ultrasonic measurement according to claim 1, characterized in that: The initialization includes configuring initial parameters.

3. The natural gas pipeline flow measurement method based on ultrasonic measurement as claimed in claim 2, characterized in that: The setting of environmental conditions includes installing a straight pipe section and setting a regulator.

4. The natural gas pipeline flow measurement method based on ultrasonic measurement as claimed in claim 3, characterized in that: The collected data is processed based on the first compensation, including obtaining the flow velocity, outputting the instantaneous value of the flow rate through the time difference method; and collecting pressure and temperature data.

5. The natural gas pipeline flow measurement method based on ultrasonic measurement as claimed in claim 4, characterized in that: The processing of the collected data based on the first compensation includes performing compensation processing on the data using the first compensation.

6. The natural gas pipeline flow measurement method based on ultrasonic measurement as claimed in claim 5, characterized in that: The monitoring and management data transmission includes transmitting the data to a central control system.

7. The natural gas pipeline flow measurement method based on ultrasonic measurement according to claim 6, characterized in that: The monitoring and management data transmission includes real-time detection of system health status, identification of anomalies and alarms, and generation of diagnostic reports to support preventive maintenance.

8. A system using the natural gas pipeline flow measurement method based on ultrasonic measurement as claimed in any one of claims 1 to 7, characterized in that: It includes measurement preparation and initialization module, data acquisition and processing module, monitoring and data management module; The path planning module is used to ensure that the measurement system is started; The data acquisition and processing module is used to acquire and process data in the natural gas pipeline in real time and output flow rate; The monitoring and data management module is used to support maintenance and data analysis through real-time monitoring and data management.

9. A computer device comprising a memory and a processor, wherein the memory stores a computer program, wherein: When the processor executes the computer program, the steps of the natural gas pipeline flow measurement method based on ultrasonic measurement as described in any one of claims 1 to 7 are implemented.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the steps of the natural gas pipeline flow measurement method based on ultrasonic measurement as described in any one of claims 1 to 7 are implemented.

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