Hydrogen-doped natural gas metering method, equipment, medium and product

Abstract

The invention discloses a metering method and device for hydrogen-doped natural gas, a medium and a product, relates to the technical field of gas metering, and aims to solve the problem that the accuracy of a metering result of the flow of the hydrogen-doped natural gas is low. The metering method of the hydrogen-doped natural gas comprises the steps that basic conditions and initial parameters are determined based on structure parameters and working condition parameters of an ultrasonic flowmeter and gas quality composition of the hydrogen-doped natural gas; on the basis of the basic conditions and the initial parameters, axial coordinate system speed distribution with the pipeline flow direction as the positive direction is determined; on the basis of speed distribution of an axial coordinate system, on the basis of a multichannel structure of the ultrasonic flowmeter and a time difference method measurement principle, the metering error and the change rule of the metering error of the ultrasonic flowmeter are predicted; on the basis of the metering error and the change rule of the ultrasonic flowmeter, the real flow of the ultrasonic flowmeter under the hydrogen doping condition is predicted according to the hydrogen doping metering verification data of the ultrasonic flowmeter.

Description

Technical Field

[0001] The present application relates to the field of gas metering technology, and in particular to a metering method, equipment, medium and product for hydrogen-blended natural gas. Background Art

[0002] Ultrasonic flowmeter, an instrument that measures fluid velocity and flow rate based on the propagation characteristics of ultrasonic waves in flowing fluids, is widely used to measure the flow rate of natural gas in long-distance natural gas pipelines.

[0003] However, long-distance pipelines usually transport hydrogen-blended natural gas. Due to the gas characteristics of hydrogen, existing ultrasonic flow meters may not be able to meet the physical property changes of hydrogen-blended natural gas, reducing the accuracy of the measurement results of hydrogen-blended natural gas flow. Summary of the Invention

[0004] The purpose of this application is to provide a method, device, medium and product for measuring hydrogen-blended natural gas, aiming to solve the problem of low accuracy of the measurement results of the flow rate of hydrogen-blended natural gas.

[0005] To achieve the above objectives, this application adopts the following technical solutions:

[0006] In a first aspect, the present application provides a method for measuring hydrogen-blended natural gas, wherein the metering equipment used for the hydrogen-blended natural gas includes:

[0007] Based on the structural parameters, operating parameters and gas composition of hydrogen-blended natural gas of the ultrasonic flowmeter, the basic conditions and initial parameters are determined. The structural parameters of the ultrasonic flowmeter include gas applicable range, pipe diameter, roughness, frequency, and signal strength. The operating parameters include pressure, temperature, and apparent flow rate. The gas composition of hydrogen-blended natural gas includes the natural gas composition before hydrogen addition and the hydrogen blending ratio used to indicate the proportion of hydrogen after hydrogen addition. On the basis of the basic conditions and initial parameters, the physical properties of hydrogen-blended natural gas of the ultrasonic flowmeter under the current metering conditions are solved based on the state equation of hydrogen-blended natural gas, and the internal flow field of the ultrasonic flowmeter is analyzed based on the turbulent flow field distribution model of fluid mechanics to determine the velocity distribution in the axial coordinate system with the pipeline flow direction as the positive direction. The physical properties of hydrogen-blended natural gas are determined based on the turbulent flow field distribution model of fluid mechanics. The parameters include viscosity, density, and Reynolds number; on the basis of the velocity distribution in the axial coordinate system, based on the multi-channel structure and time difference measurement principle of the ultrasonic flowmeter, the relationship between the time difference of the ultrasonic signal propagating in the forward and countercurrent directions of the gas fluid in the pipeline and the fluid flow velocity is used to solve the cross-sectional flow velocity of the gas pipeline, and the influence of different hydrogen doping ratios on the gas physical properties, flow field distribution, and ultrasonic signal propagation is analyzed to predict the measurement error of the ultrasonic flowmeter and its variation law; on the basis of the measurement error of the ultrasonic flowmeter and its variation law, according to the data of the hydrogen doping measurement verification of the ultrasonic flowmeter, the actual flow rate of the ultrasonic flowmeter under hydrogen doping is predicted. The data of the hydrogen doping measurement verification of the ultrasonic flowmeter include the error parameters of the flow rate and the standard flow rate of the ultrasonic flowmeter under different hydrogen doping ratios.

[0008] The method for measuring hydrogen-blended natural gas provided in the embodiments of the present application can analyze the flow field and characteristic parameters of ultrasonic flow meters in service on long-distance natural gas pipelines based on the time-difference flow measurement principle and the physical property changes of hydrogen-blended natural gas, simulate the metering process of the ultrasonic flow meter, determine the changes in its flow measurement accuracy, and then predict the actual flow rate of the hydrogen-blended natural gas.

[0009] In some embodiments, the method further includes: determining evaluation information based on the actual flow rate and the apparent flow rate, where the evaluation information is used to indicate whether the error parameter meets the process accuracy requirement.

[0010] In some embodiments, the method further includes: determining a correction coefficient based on the actual flow rate and the apparent flow rate, wherein the correction coefficient is used to correct the error parameter.

[0011] In some embodiments, the above-mentioned method of "predicting the actual flow rate of the ultrasonic flow meter under hydrogen doping conditions based on the data of the ultrasonic flow meter's hydrogen doping measurement and calibration" includes: in the presence of data of the ultrasonic flow meter's hydrogen doping measurement and calibration, using a deep learning model or a simulation model to predict the actual flow rate.

[0012] In some embodiments, the method also includes: in the absence of data on hydrogen doping calibration of the ultrasonic flowmeter, selecting the ultrasonic flowmeter's apparent flow rate, Reynolds number, hydrogen doping ratio, and ultrasonic sound velocity as four characteristic input parameters, using the actual flow rate as the characteristic output parameter, and using a deep learning model for simulation training to ultimately predict the actual flow rate.

[0013] In some embodiments, the ultrasonic flow meter satisfies the following formula:

[0014]

[0015] Where v is the axial flow velocity of the medium or the average velocity on the sound channel line; c is the sound wave transmission velocity of the ultrasonic signal; L is the sound channel length; θ is the angle between the sound channel line and the pipeline axis; t down is the propagation time of the sound wave in the pipeline medium; t up is the countercurrent propagation time of the sound wave in the pipeline medium.

[0016] In some embodiments, the state equation of the hydrogen-blended natural gas is the BWRS equation.

[0017] In some embodiments, the turbulent flow field distribution model is used to characterize the axial fluid velocity distribution with the pipeline flow direction as the positive direction. The turbulent flow field distribution model satisfies the following formula:

[0018]

[0019]

[0020] Where, u is the velocity; R is the inner diameter of the tube or ultrasonic flowmeter, n is the velocity distribution coefficient, K r is the wall roughness, and Re is the Reynolds number.

[0021] In some embodiments, the overall structure of the ultrasonic flowmeter is a pipe covered with a built-in ultrasonic transmitting and receiving probe. The main structural parameters include inner diameter, number of channels, channel angle, channel position, and ultrasonic signal emission intensity. The cross-sectional average flow velocity of the ultrasonic flowmeter is calculated as multi-channel weighted fusion, and the weighted fusion satisfies the following formula:

[0022]

[0023] Where V is the average flow velocity in the pipe section, W i is the weighted value of the i-th channel, V i is the average flow velocity of the ith channel, and n is the number of channels of the ultrasonic flowmeter.

[0024] In some embodiments, the attenuation model of the change in the ultrasonic signal synchronous hydrogen doping ratio in the ultrasonic flow meter satisfies the following formula:

[0025] P=P0·e -α·x ;

[0026]

[0027] Among them, P is the sound pressure intensity of the sound wave, P0 is the sound pressure intensity at the sound wave transmitting end, α is the sound wave attenuation coefficient, x is the distance from the sound wave transmitting end, w is the angular frequency of the ultrasonic wave, ρ0 is the density, a is the ultrasonic signal propagation speed, u is the viscosity, k is the thermal conductivity, c v 、c p are the heat capacities at constant volume and constant pressure, respectively.

[0028] In a second aspect, the present application provides a metering device for hydrogen-blended natural gas, which is applied to metering equipment for hydrogen-blended natural gas. The device includes: a processing module.

[0029] The processing module is used to determine the basic conditions and initial parameters based on the structural parameters, operating parameters and gas composition of hydrogen-blended natural gas of the ultrasonic flowmeter. The structural parameters of the ultrasonic flowmeter include gas applicable range, pipe diameter, roughness, frequency, and signal strength. The operating parameters include pressure, temperature, and apparent flow rate. The gas composition of hydrogen-blended natural gas includes the natural gas gas composition before hydrogen addition and the hydrogen addition ratio used to indicate the proportion of hydrogen after hydrogen addition. The processing module is also used to solve the physical parameters of hydrogen-blended natural gas of the ultrasonic flowmeter under the current metering working conditions based on the state equation of hydrogen-blended natural gas on the basis of the basic conditions and initial parameters, and to analyze the internal flow field of the ultrasonic flowmeter based on the turbulent flow field distribution model of fluid mechanics, to determine the velocity distribution in the axial coordinate system with the pipeline flow direction as the positive direction, and the physical parameters of hydrogen-blended natural gas. The parameters include viscosity, density, and Reynolds number; the processing module is also used to solve the cross-sectional flow velocity of the gas pipeline based on the velocity distribution in the axial coordinate system, based on the multi-channel structure of the ultrasonic flowmeter and the time difference measurement principle, and the relationship between the time difference of the ultrasonic signal propagating in the forward and countercurrent directions of the gas fluid in the pipeline and the fluid flow velocity, and analyze the influence of different hydrogen doping ratios on the gas properties, flow field distribution, and ultrasonic signal propagation, and predict the measurement error of the ultrasonic flowmeter and its changing law; the processing module is also used to predict the actual flow of the ultrasonic flowmeter under hydrogen doping conditions based on the measurement error of the ultrasonic flowmeter and its changing law, according to the data of the hydrogen doping measurement calibration of the ultrasonic flowmeter. The data of the hydrogen doping measurement calibration of the ultrasonic flowmeter include the error parameters of the flow rate and the standard flow rate of the ultrasonic flowmeter under different hydrogen doping ratios.

[0030] In a third aspect, the present application provides a hydrogen-blended natural gas metering device, the device comprising: a processor and a memory, the processor and the memory being coupled, the memory being used to store one or more programs, the one or more programs comprising computer-executable instructions, and when the hydrogen-blended natural gas metering device is running, the processor executes the computer-executable instructions stored in the memory to implement any of the hydrogen-blended natural gas metering methods described in the first aspect above.

[0031] In a fourth aspect, the present application provides a computer-readable storage medium, in which instructions are stored. When the instructions are executed on a computer, the computer executes any of the hydrogen-blended natural gas metering methods described in the first aspect.

[0032] In a fifth aspect, the present application provides a computer program product applied to a metering device for hydrogen-blended natural gas, the computer program product including computer instructions. When the computer instructions are executed on the metering device for hydrogen-blended natural gas, the metering device for hydrogen-blended natural gas implements any of the metering methods for hydrogen-blended natural gas described in the first aspect above.

[0033] In the above solution, the technical problems that can be solved and the technical effects achieved by the metering device, equipment, computer storage medium or computer program product of hydrogen-blended natural gas can be referred to the technical problems and technical effects solved by the first aspect above, and will not be repeated here. BRIEF DESCRIPTION OF THE DRAWINGS

[0034] In order to more clearly illustrate the technical solutions of the embodiments of the present application, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without any creative work.

[0035] Figure 1 A schematic structural diagram of a hydrogen-blended natural gas metering system provided in an embodiment of the present application;

[0036] Figure 2 A schematic flow chart of a method for measuring hydrogen-blended natural gas provided in an embodiment of the present application;

[0037] Figure 3 A schematic diagram of the internal flow field of an ultrasonic flow meter provided in an embodiment of the present application;

[0038] Figure 4 A schematic diagram of an ultrasonic flowmeter structure and ultrasonic signal transmitting and receiving ends provided in an embodiment of the present application;

[0039] Figure 5A schematic diagram of another ultrasonic flowmeter structure and ultrasonic signal transmitting and receiving end provided in an embodiment of the present application;

[0040] Figure 6 A schematic diagram of the process of constructing an ultrasonic flowmeter mechanism model provided in an embodiment of the present application;

[0041] Figure 7 This is a graph showing the measurement accuracy prediction results of an ultrasonic flowmeter under different hydrogen blending ratios provided in an embodiment of the present application;

[0042] Figure 8 A schematic structural diagram of a hydrogen-blended natural gas metering device provided in an embodiment of the present application;

[0043] Figure 9 A schematic diagram of the structure of a hydrogen-blended natural gas metering device provided in an embodiment of the present application;

[0044] Figure 10 A conceptual partial view of a computer program product provided in an embodiment of the present application. DETAILED DESCRIPTION

[0045] The following will be combined with the drawings in the embodiments of this application to clearly and completely describe the technical solutions in the embodiments of this application. Obviously, the embodiments described are only part of the embodiments of this application, not all of the embodiments. Based on the embodiments in this application, all other embodiments obtained by ordinary technicians in this field without making creative efforts are within the scope of protection of this application.

[0046] In the description of this application, it should be understood that the terms "upper," "lower," "left," "right," "front," "back," "inner," "outer," and the like, indicating directions or positional relationships, are based on the directions or relative positional relationships shown in the accompanying drawings and are intended solely to facilitate the description of this application and simplify the description. They do not indicate or imply that the devices or components referred to must have a specific direction, be constructed, or operate in a specific direction. Therefore, they should not be construed as limitations on this application. Unless otherwise specified, the above-mentioned directionality descriptions may be flexibly set in actual application, provided that the relative positional relationships shown in the accompanying drawings are met.

[0047] The terms "first" and "second" are used for descriptive purposes only and should not be construed as indicating or implying relative importance or implicitly specifying the number of the technical features being referred to. Thus, a feature specified as "first" or "second" may explicitly or implicitly include one or more of such features. Throughout this application, unless otherwise specified, "plurality" means two or more.

[0048] In the description of this application, it should be noted that, unless otherwise expressly specified or limited, the terms "mounted," "connected," "connected," and "connected" should be understood broadly. For example, they may refer to fixed connections, detachable connections, or integral connections. They may be directly connected, indirectly connected through an intermediary, or internally connected between two components. Those skilled in the art will understand the specific meanings of these terms in this application based on the specific circumstances.

[0049] In the embodiments of the present application, the terms "comprises," "comprising," or any other variations thereof are intended to encompass non-exclusive inclusion, such that a process, article, or device comprising a series of elements includes not only those elements but also other elements not explicitly listed, or elements inherent to such process, article, or device. In the absence of further limitations, an element defined by the phrase "comprising a ..." does not preclude the presence of other identical elements in the process, article, or device comprising the element.

[0050] In the embodiments of this application, words such as "exemplary" or "for example" are used to indicate examples, illustrations, or descriptions. Any embodiment or design described as "exemplary" or "for example" in the embodiments of this application should not be interpreted as being preferred or advantageous over other embodiments or designs. Rather, the use of words such as "exemplary" or "for example" is intended to present the relevant concepts in a concrete manner.

[0051] In the description of this specification, specific features, structures, materials or characteristics may be combined in an appropriate manner in any one or more embodiments or examples.

[0052] As a zero-emission clean energy source, hydrogen has great development potential. It can be used to absorb surplus electricity from renewable energy sources such as wind, solar, and hydropower, and improve the stability and redundancy of the energy internet. Utilizing existing natural gas pipelines and other infrastructure to transport hydrogen is an economical and effective means of achieving large-scale hydrogen transportation. However, hydrogen blending into natural gas significantly changes its physical properties and affects the accuracy and adaptability of metering equipment. Ultrasonic flowmeters, with their zero pressure drop, zero throttling, high accuracy, and easy maintenance, are beneficial for energy conservation, cost reduction, and efficiency improvement in long-distance natural gas pipelines. Therefore, they are increasingly used in natural gas pipelines. However, current research on ultrasonic flowmeters for hydrogen blending and complex operating conditions remains insufficient.

[0053] During actual production operations, ultrasonic flowmeters must first undergo standard calibration at a metrology verification station. Multiple sets of metrology verification tests are conducted against high-precision (0.3%) standard flowmeters under the same flow rate, pipe diameter, temperature, pressure, and gas composition to verify that their metering accuracy meets the standards and that the error is within the allowable range. Otherwise, evaluation / correction or return to the factory is required. Natural gas flowmeter calibration stations rarely perform metrology verification under hydrogen-blended gas composition conditions to ensure operational safety and minimize equipment lifespan. However, high-precision metrology verification is often not possible during field trials of hydrogen-blended natural gas pipeline transportation.

[0054] Currently, domestic and international scholars primarily study the metrological adaptability of ultrasonic flowmeters through computational fluid dynamics (CFD) numerical simulations and indoor flow loop experiments. However, the conditions in indoor flow loops differ from those in large-diameter on-site pipelines, making it difficult for CFD numerical simulations to describe the propagation process of ultrasonic signals. Furthermore, CFD numerical simulations suffer from complex modeling, operational difficulties, long time consumption, and difficulty in application. In the era of artificial intelligence (AI), intelligent machine learning algorithms can be trained directly using field data (flowmeter calibration data), resulting in analytical and evaluation models that can predict ultrasonic flowmeter performance. However, these predictive models lack comprehensive physical theory support and suffer from deficiencies in extensibility, reliability, and stability. The current trend in intelligent development is the integration and improvement of physical models and intelligent algorithms.

[0055] Therefore, an embodiment of the present application provides a method for measuring hydrogen-blended natural gas. By using an ultrasonic flow meter in service on a long-distance natural gas pipeline, based on the time-difference flow measurement principle and the physical property changes of the hydrogen-blended natural gas, the flow field and characteristic parameters are analyzed, the metering process of the ultrasonic flow meter is simulated, and the change in its flow metering accuracy is determined, thereby predicting the actual flow of the hydrogen-blended natural gas.

[0056] In addition, the embodiment of the present application can also provide an evaluation indicating whether the error parameter meets the process accuracy requirements, and a correction coefficient for correcting the error parameter based on the change in flow measurement accuracy.

[0057] In this regard, the present application provides a metering system for hydrogen-blended natural gas, such as Figure 1 As shown, it includes metering equipment for hydrogen-blended natural gas and an ultrasonic flow meter.

[0058] The hydrogen-blended natural gas metering equipment can obtain the structural and operating parameters of the ultrasonic flowmeter and, based on the gas composition of the hydrogen-blended natural gas in the pipeline, determine the velocity distribution in the axial coordinate system, with the pipeline flow direction as the positive direction. The hydrogen-blended natural gas metering equipment can then predict the ultrasonic flowmeter's measurement error and its variation based on the axial coordinate velocity distribution. Furthermore, by combining the error parameters between the ultrasonic flowmeter's flow rate and the standard flow rate at different hydrogen blending ratios, the equipment can predict the ultrasonic flowmeter's actual flow rate under hydrogen blending conditions.

[0059] In other words, this application can take ultrasonic flowmeters as the main research object, integrate mechanism models and artificial intelligence algorithms, and consider the influencing factors of natural gas hydrogen blending as comprehensively as possible, and is easier to operate and apply in practical applications than numerical simulation software.

[0060] It should be noted that, in the embodiment of the present application, the metering device for hydrogen-blended natural gas and the ultrasonic flow meter may be integrated devices; or, the metering device for hydrogen-blended natural gas and the ultrasonic flow meter may be two separately deployed devices.

[0061] Wherein, in the case where the metering device for hydrogen-blended natural gas and the ultrasonic flow meter are two separately deployed devices, the metering device for hydrogen-blended natural gas may be a terminal or a server.

[0062] The server can be a single physical server or a server cluster consisting of multiple servers. Alternatively, the server cluster can be a distributed cluster. Alternatively, the server can be a cloud server. The embodiments of this application do not limit the specific implementation of the server.

[0063] The terminal may be a mobile phone, tablet computer, desktop computer, laptop computer, handheld computer, notebook computer, ultra-mobile personal computer (UMPC), netbook computer, or other device with transceiver functions. This application does not impose any particular restrictions on the specific form of the terminal. The terminal may interact with the user through one or more methods such as a keyboard, touchpad, touch screen, remote control, voice interaction, or handwriting device.

[0064] After introducing the application scenario and implementation environment of the embodiment of the present application, the metering method of hydrogen-blended natural gas provided by the embodiment of the present application is described in detail below in combination with the above implementation environment.

[0065] The methods in the following embodiments can all be implemented in the above application scenarios and implementation environments. The embodiments of the present application are described in detail below with reference to the accompanying drawings.

[0066] Figure 2This is a flow chart of a method for measuring hydrogen-blended natural gas provided in an embodiment of the present application. Figure 2 As shown, the method is applied to a metering device for hydrogen-blended natural gas, and includes: S201-S204.

[0067] S201. Determine basic conditions and initial parameters based on the structural parameters and operating parameters of the ultrasonic flowmeter and the gas quality composition of the hydrogen-blended natural gas.

[0068] Among them, the structural parameters of the ultrasonic flowmeter include the gas application range, pipe diameter, roughness, frequency, signal strength, etc., the operating parameters include pressure, temperature, and apparent flow rate, and the gas composition of hydrogen-blended natural gas includes the natural gas gas composition before hydrogen blending and the hydrogen blending ratio used to indicate the proportion of hydrogen after hydrogen blending.

[0069] It should be noted that the hydrogen doping ratio will directly affect the calculation of physical parameters (such as density and viscosity) in the subsequent S202, and affect the ultrasonic signal propagation time difference through the subsequent flow field model in S203, and finally participate in the prediction of the correction coefficient as an input parameter in S204.

[0070] S202. Based on the basic conditions and initial parameters, the physical properties of the hydrogen-blended natural gas under the current metering conditions of the ultrasonic flowmeter are solved based on the hydrogen-blended natural gas state equation, and the internal flow field of the ultrasonic flowmeter is analyzed based on the turbulent flow field distribution model of fluid mechanics to determine the velocity distribution in the axial coordinate system with the pipeline flow direction as the positive direction.

[0071] Among them, the physical properties of hydrogen-blended natural gas include viscosity, density, and Reynolds number.

[0072] It should be noted that for the introduction of the velocity distribution in the axial coordinate system, please refer to Figure 3 Schematic diagram of the internal flow field of the ultrasonic flowmeter shown.

[0073] S203. On the basis of the velocity distribution in the axial coordinate system, based on the multi-channel structure of the ultrasonic flowmeter and the time difference measurement principle, the cross-sectional flow velocity of the gas pipeline is solved by utilizing the relationship between the time difference of the ultrasonic signal propagating in the forward and reverse directions of the gas fluid in the pipeline and the fluid flow velocity, and the influence of different hydrogen blending ratios on the gas properties, flow field distribution, and ultrasonic signal propagation is analyzed to predict the measurement error of the ultrasonic flowmeter and its variation law.

[0074] S204. Based on the measurement error of the ultrasonic flowmeter and its variation pattern, and according to the data of hydrogen doping measurement verification of the ultrasonic flowmeter, predict the actual flow rate of the ultrasonic flowmeter under hydrogen doping conditions.

[0075] Among them, the data of ultrasonic flowmeter hydrogen doping measurement verification includes the error parameters of ultrasonic flowmeter flow rate and standard flow rate under different hydrogen doping ratios.

[0076] That is to say, by targeting the ultrasonic flowmeters in service on long-distance natural gas pipelines, based on the time-difference flow measurement principle and the physical property changes of hydrogen-blended natural gas, their flow fields and characteristic parameters are analyzed, the metering process of the ultrasonic flowmeters is simulated, the changes in their flow measurement accuracy are determined, and then the actual flow of hydrogen-blended natural gas is predicted.

[0077] In some embodiments, after predicting the actual flow rate of the ultrasonic flowmeter under hydrogen blending conditions (i.e., S204), the metering equipment of the hydrogen-blended natural gas can determine evaluation information based on the actual flow rate and the displayed flow rate. The evaluation information is used to indicate whether the error parameters meet the process accuracy requirements.

[0078] In other embodiments, after predicting the actual flow rate of the ultrasonic flowmeter under hydrogen blending conditions (i.e., S204), the metering equipment for hydrogen-blended natural gas can determine a correction coefficient based on the actual flow rate and the displayed flow rate. The correction coefficient is used to correct the error parameter referenced during the preset process.

[0079] As a possible implementation manner, the correction coefficient may be a ratio between the actual flow rate and the apparent flow rate.

[0080] In some embodiments, the metering equipment for hydrogen-blended natural gas may classify the operating conditions based on whether there is data from hydrogen-blended metering verification of the ultrasonic flowmeter.

[0081] As a possible implementation method, in the presence of data from hydrogen-blended metering and calibration of ultrasonic flowmeters, the metering equipment for hydrogen-blended natural gas can use deep learning models or simulation models to predict the actual flow rate.

[0082] As another possible implementation method, in the absence of data on hydrogen-doped metering calibration of ultrasonic flowmeters, the metering equipment for hydrogen-doped natural gas can select the ultrasonic flowmeter's apparent flow rate, Reynolds number, hydrogen doping ratio, and ultrasonic sound velocity as four characteristic input parameters, and the actual flow rate as the characteristic output parameter. A deep learning model can be used for simulation training to ultimately predict the actual flow rate of the ultrasonic flowmeter under hydrogen doping conditions.

[0083] In some embodiments, the ultrasonic flow meter is a natural gas pipeline multi-channel ultrasonic flow meter using the time difference method. The principle can be seen in the following formulas 1 to 3:

[0084]

[0085] Where v is the axial flow velocity of the medium or the average velocity on the sound channel line; c is the sound wave transmission velocity of the ultrasonic signal; L is the sound channel length; θ is the angle between the sound channel line and the pipeline axis; t down is the propagation time of the sound wave in the pipeline medium; tup is the countercurrent propagation time of the sound wave in the pipeline medium.

[0086] In some embodiments, the hydrogen-blended natural gas state equation for solving the ultrasonic flowmeter measurement-related physical property parameters can use the BWRS equation (such as the following formula 4), which can more accurately calculate the physical properties of hydrogen-blended natural gas within the hydrogen blending ratio range of 0-30%.

[0087]

[0088] Where p is pressure, T is temperature, R is the universal gas constant, and A0, B0, C0, D0, E0, a, b, c, d, γ, and ρ are gas-specific constants.

[0089] In some embodiments, the turbulent flow field distribution model is used to characterize the axial fluid velocity distribution with the pipeline flow direction as the positive direction. The turbulent flow field distribution model satisfies the following formulas 5 to 7:

[0090]

[0091] Where, u is the velocity; R is the inner diameter of the tube or ultrasonic flowmeter, n is the velocity distribution coefficient, K r is the wall roughness, and Re is the Reynolds number.

[0092] In some embodiments, the multi-channel ultrasonic flowmeter is a common natural gas pipeline ultrasonic flowmeter. The overall structure is a pipeline covered with a built-in ultrasonic transmitting and receiving probe. The main structural parameters include inner diameter, number of channels, channel angle, channel position, ultrasonic signal emission intensity, etc. (used for mechanism modeling of ultrasonic flowmeter), and the built-in probe basically fits the inner wall of the pipeline, and the impact on the flow field can be ignored.

[0093] The cross-sectional average flow velocity of the ultrasonic flowmeter is calculated as multi-channel weighted fusion, as shown in the following formula 8:

[0094]

[0095] Where V is the average flow velocity in the pipe section, W i is the weighted value of the i-th channel, V i is the average flow velocity of the ith channel, and n is the number of channels of the ultrasonic flowmeter.

[0096] For example, Figure 4 and Figure 5 As shown in the figure, the ultrasonic flow meter structure and the ultrasonic signal transmitting and receiving end schematic diagram are respectively shown.

[0097] In some embodiments, hydrogen doping has an adverse effect on the propagation of ultrasonic flowmeter signals. An increase in the hydrogen doping ratio will increase the attenuation of the ultrasonic signal. The attenuation model of the ultrasonic signal in the ultrasonic flowmeter synchronized with the change in the hydrogen doping ratio satisfies the following formulas 9 and 10:

[0098] P=P0·e -α·x Formula 9;

[0099]

[0100] Among them, P is the sound pressure intensity of the sound wave, P0 is the sound pressure intensity at the sound wave transmitting end, α is the sound wave attenuation coefficient, x is the distance from the sound wave transmitting end, w is the angular frequency of the ultrasonic wave, ρ0 is the density, a is the ultrasonic signal propagation speed, u is the viscosity, k is the thermal conductivity, c v 、c p are the heat capacities at constant volume and constant pressure, respectively.

[0101] The following describes the method for measuring hydrogen-blended natural gas provided in this application in conjunction with specific embodiments.

[0102] like Figure 6 As shown in the figure, it shows a schematic diagram of the process of constructing the ultrasonic flowmeter mechanism model. Among them, by obtaining the measurement working condition / state parameters, ultrasonic flowmeter structural parameters, and gas composition (hydrogen doping ratio), the hydrogen doping physical parameters are solved. Then, the internal flow field structure (flow velocity distribution) is solved for different sound channels. i , V i Then, based on the acoustic channel coupling, the cross-sectional flow velocity is solved to determine the effect of hydrogen doping. After that, the results of the hydrogen doping physical property parameters and the effect of hydrogen doping are used as the key parameters of the composite model, and the existence of verification data is determined.

[0103] If calibration data is available, deep learning network training and prediction are performed to obtain the true volume flow rate and correction coefficient.

[0104] If there is no calibration data, the ultrasonic simulation model correction prediction is performed to obtain the true volume flow rate and correction coefficient.

[0105] The following describes the method for measuring hydrogen-blended natural gas provided in this application based on the ultrasonic measurement mechanism with reference to specific examples.

[0106] For example, taking the prediction of the metering accuracy of an ultrasonic flow meter in a pipeline as an example, the metering accuracy and adaptability of the ultrasonic flow meter are evaluated.

[0107] An intermediate station of a long-distance natural gas pipeline uses an ultrasonic flowmeter as the main equipment for natural gas volume measurement, with a measurement accuracy requirement of ±1%.

[0108] The structural parameters of the ultrasonic flowmeter are DN250, which is a small-caliber ultrasonic flowmeter. It adopts a four-channel vertically evenly divided arrangement (as mentioned above). Figure 4 and Figure 5 As shown), the sound channel angle is 45 degrees, the metering medium under normal conditions is natural gas (methane content is 96.1%), the operating temperature is 20-25°C, the pressure is 5.5-7MPa, the expected hydrogen blending ratio is 0-30%, the sound pressure at the ultrasonic signal transmitting end is 100uPa, and the transmitting frequency is calculated at 40kHz and 200kHz respectively.

[0109] In this station, the technical method of the present invention is used to predict and evaluate the metering adaptability of the ultrasonic flowmeter under different hydrogen blending ratios.

[0110] The results are shown in Tables 1 and 2 below.

[0111] Table 1 Changes in measurement accuracy of a certain type of ultrasonic flowmeter

[0112]

[0113] Table 2 Ultrasonic attenuation calculation results

[0114]

[0115] In addition, taking the four-channel ultrasonic measurement error as an example, Figure 7 The figure shows the predicted measurement accuracy of the ultrasonic flowmeter under different hydrogen doping ratios, including the corresponding errors for no hydrogen doping, 10% hydrogen doping, and 30% hydrogen doping. The ultrasonic flowmeter's measurement accuracy under no hydrogen doping is within 1%, which is consistent with actual field production experience and design specifications.

[0116] In summary, the method for measuring hydrogen-blended natural gas provided by the technical solution of this application can achieve the following effects:

[0117] 1. The ultrasonic flowmeter mechanism model in this application can characterize and describe the structural parameters of the ultrasonic flowmeter (inner diameter, number of sound channels, sound channel position, etc.). The hydrogen doping physical property model and fluid mechanics turbulence distribution can reflect the impact of the physical property changes of natural gas caused by hydrogen doping on the ultrasonic flowmeter measurement in the flow field, parameters and measurement results.

[0118] 2. As a rapidly developing emerging technology field, artificial intelligence machines can directly achieve the predictive effect of the mechanism model by continuously analyzing massive amounts of data. For the complex process conditions at the pipeline metering project site and the hidden influencing factors that are not covered in the mechanism model, machine analysis algorithms can be used to extract knowledge and experience from the calibration data to predict the metering accuracy of the ultrasonic flowmeter. Deep artificial neural network algorithms are suitable for simulations with sufficient field experience data. When there is a lack of field experience data and operating parameters (such as evaluating hydrogen-doped ultrasonic flowmeters in new pipelines), the mechanism model can also be used to predict the metering accuracy of the ultrasonic flowmeter.

[0119] 3. This application's ultrasonic mechanism model and hydrogen doping metering prediction, evaluation, and correction method, based on a well-established mechanism model and machine learning algorithm for ultrasonic flowmeter multi-channel metering, can directly and quickly derive the metering accuracy of ultrasonic flowmeters under varying hydrogen doping conditions. Compared to existing methods such as CFD numerical simulation, indoor loop experiments, and simple metering prediction models, this method offers advantages such as speed, high accuracy, and strong scalability.

[0120] The above mainly introduces the solution provided by the embodiment of the present application from the perspective of computer equipment. It can be understood that in order to realize the above functions, the computer equipment includes hardware structures and / or software modules corresponding to the execution of each function. Those skilled in the art should easily realize that, in combination with the steps of the metering method of hydrogen-blended natural gas described in each example of the embodiment disclosed in this application, the present application can be implemented in the form of hardware or a combination of hardware and computer software. Whether a function is executed in the form of hardware or computer software driving hardware depends on the specific application and design constraints of the technical solution. Professional and technical personnel can use different methods to implement the described functions for each specific application, but such implementation should not be considered to be beyond the scope of this application.

[0121] The present application also provides a hydrogen-blended natural gas metering device. The hydrogen-blended natural gas metering device can be a computer device, a CPU in the computer device, a processing module in the computer device for metering hydrogen-blended natural gas, or a client in the computer device for metering hydrogen-blended natural gas.

[0122] In the embodiment of the present application, the metering device for hydrogen-blended natural gas can be divided into functional modules or functional units according to the above-mentioned method example. For example, each functional module or functional unit can be divided according to each function, or two or more functions can be integrated into one processing module. The above-mentioned integrated module can be implemented in the form of hardware or in the form of software functional modules or functional units. Among them, the division of modules or units in the embodiment of the present application is schematic and is only a logical functional division. In actual implementation, there may be other division methods.

[0123] like Figure 8 , which is a schematic structural diagram of a hydrogen-blended natural gas metering device provided in an embodiment of the present application. The hydrogen-blended natural gas metering device 800 is applied to hydrogen-blended natural gas metering equipment, and the hydrogen-blended natural gas metering device 800 may include: a processing module 801.

[0124] The processing module 801 is used to determine the basic conditions and initial parameters based on the structural parameters, operating parameters and gas quality composition of the hydrogen-blended natural gas of the ultrasonic flowmeter. The structural parameters of the ultrasonic flowmeter include the gas applicable range, pipe diameter, roughness, frequency, and signal strength. The operating parameters include pressure, temperature, and apparent flow rate. The gas quality composition of the hydrogen-blended natural gas includes the natural gas composition before hydrogen addition and the hydrogen addition ratio used to indicate the proportion of hydrogen after hydrogen addition. The processing module 801 is also used to solve the physical properties of the hydrogen-blended natural gas of the ultrasonic flowmeter under the current metering working conditions based on the state equation of the hydrogen-blended natural gas on the basis of the basic conditions and initial parameters, and to analyze the internal flow field of the ultrasonic flowmeter based on the turbulent flow field distribution model of fluid mechanics to determine the velocity distribution in the axial coordinate system with the pipeline flow direction as the positive direction. The physical properties of the hydrogen-blended natural gas The parameters include viscosity, density, and Reynolds number. The processing module 801 is further used to solve the cross-sectional flow velocity of the gas pipeline based on the velocity distribution in the axial coordinate system, the multi-channel structure of the ultrasonic flowmeter, and the time difference measurement principle. The relationship between the time difference of the ultrasonic signal propagating in the forward and countercurrent directions of the gas fluid in the pipeline and the fluid flow velocity is used to analyze the influence of different hydrogen doping ratios on the gas properties, flow field distribution, and ultrasonic signal propagation, and predict the measurement error of the ultrasonic flowmeter and its variation law. The processing module 801 is also used to predict the actual flow rate of the ultrasonic flowmeter under hydrogen doping based on the measurement error of the ultrasonic flowmeter and its variation law, according to the data of the hydrogen doping measurement verification of the ultrasonic flowmeter. The data of the hydrogen doping measurement verification of the ultrasonic flowmeter includes the error parameters between the flow rate and the standard flow rate of the ultrasonic flowmeter under different hydrogen doping ratios.

[0125] Optionally, the processing module 801 is further configured to determine evaluation information based on the actual flow rate and the apparent flow rate, where the evaluation information is used to indicate whether the error parameter meets the process accuracy requirement.

[0126] Optionally, the processing module 801 is further configured to determine a correction coefficient based on the actual flow rate and the displayed flow rate, and the correction coefficient is used to correct the error parameter.

[0127] Optionally, the processing module 801 is specifically configured to use a deep learning model or a simulation model to predict the actual flow rate when data of hydrogen doping measurement and calibration of an ultrasonic flow meter is available.

[0128] Optionally, the processing module 801 is also used to select the ultrasonic flowmeter's apparent flow rate, Reynolds number, hydrogen doping ratio, and ultrasonic sound velocity as four characteristic input parameters when there is no data on the ultrasonic flowmeter's hydrogen doping measurement and calibration, and use the actual flow rate as the characteristic output parameter, use a deep learning model for simulation training, and ultimately predict the actual flow rate.

[0129] Optionally, the ultrasonic flow meter satisfies the following formula:

[0130]

[0131] Where v is the axial flow velocity of the medium or the average velocity on the sound channel line; c is the sound wave transmission velocity of the ultrasonic signal; L is the sound channel length; θ is the angle between the sound channel line and the pipeline axis; t down is the propagation time of the sound wave in the pipeline medium; t up is the countercurrent propagation time of the sound wave in the pipeline medium.

[0132] Optionally, the state equation of hydrogen-blended natural gas is a BWRS equation.

[0133] Optionally, a turbulent flow field distribution model is used to characterize the axial fluid velocity distribution with the pipeline flow direction as the positive direction. The turbulent flow field distribution model satisfies the following formula:

[0134]

[0135] Where, u is the velocity; R is the inner diameter of the tube or ultrasonic flowmeter, n is the velocity distribution coefficient, K r is the wall roughness, and Re is the Reynolds number.

[0136] Optionally, the overall structure of the ultrasonic flowmeter is a pipe covered with a built-in ultrasonic transmitting and receiving probe. The main structural parameters include inner diameter, number of channels, channel angle, channel position, and ultrasonic signal emission intensity. The cross-sectional average flow velocity of the ultrasonic flowmeter is calculated as multi-channel weighted fusion, and the weighted fusion satisfies the following formula:

[0137]

[0138] Where V is the average flow velocity in the pipe section, W i is the weighted value of the i-th channel, Vi is the average flow velocity of the ith channel, and n is the number of channels of the ultrasonic flowmeter.

[0139] Optionally, the attenuation model of the change in the ultrasonic signal synchronous hydrogen doping ratio in the ultrasonic flowmeter satisfies the following formula:

[0140] P=P0·e -α·x ;

[0141]

[0142] Among them, P is the sound pressure intensity of the sound wave, P0 is the sound pressure intensity at the sound wave transmitting end, α is the sound wave attenuation coefficient, x is the distance from the sound wave transmitting end, w is the angular frequency of the ultrasonic wave, ρ0 is the density, a is the ultrasonic signal propagation speed, u is the viscosity, k is the thermal conductivity, c v 、c p are the heat capacities at constant volume and constant pressure, respectively.

[0143] Figure 9 9 is a schematic diagram illustrating a structure of a hydrogen-blended natural gas metering device according to an exemplary embodiment. The hydrogen-blended natural gas metering device may include a processor 902 configured to execute application code to implement the hydrogen-blended natural gas metering method of the present application.

[0144] The processor 902 may be a CPU, a microprocessor, an application-specific integrated circuit (ASIC), or one or more integrated circuits for controlling the execution of the program of the present application.

[0145] like Figure 9 As shown, the metering device for hydrogen-blended natural gas may further include a memory 903. The memory 903 is used to store application code for executing the solution of the present application, and is controlled by the processor 902 for execution.

[0146] The memory 903 may be a read-only memory (ROM) or other type of static storage device that can store static information and instructions, a random access memory (RAM) or other type of dynamic storage device that can store information and instructions, or an electrically erasable programmable read-only memory (EEPROM), a compact disc read-only memory (CD-ROM) or other optical disc storage, an optical disc storage (including a compact disc, laser disc, optical disc, digital versatile disc, Blu-ray disc, etc.), a magnetic disk storage medium or other magnetic storage device, or any other medium that can be used to carry or store desired program code in the form of instructions or data structures and can be accessed by a computer, but is not limited thereto. The memory 903 may exist independently and be connected to the processor 902 via the bus 904. The memory 903 may also be integrated with the processor 902.

[0147] like Figure 9 As shown, the metering device for hydrogen-blended natural gas may further include a communication interface 901, wherein the communication interface 901, the processor 902, and the memory 903 may be coupled to each other, for example, via a bus 904. The communication interface 901 is used to exchange information with other devices, for example, to support information exchange between the metering device for hydrogen-blended natural gas and other devices.

[0148] It should be pointed out that Figure 9 The equipment structure shown in the figure does not constitute a limitation on the metering equipment for hydrogen-blended natural gas. Figure 9 In addition to the components shown, the metering device for hydrogen-blended natural gas may include more or fewer components than shown, or a combination of certain components, or a different arrangement of components.

[0149] In actual implementation, the functions implemented by the processing module 801 can be Figure 9 The processor 902 shown calls the program code in the memory 903 to implement it.

[0150] The present application also provides a computer-readable storage medium having instructions stored thereon. When the instructions in the computer-readable storage medium are executed by a processor of a computer device, the computer device is enabled to perform the metering of hydrogen-blended natural gas provided in the above-described embodiment. For example, the computer-readable storage medium may be a memory 903 including instructions, and the instructions may be executed by the processor 902 of the computer device to perform the above-described method. Alternatively, the computer-readable storage medium may be a non-transitory computer-readable storage medium, such as a ROM, RAM, CD-ROM, magnetic tape, floppy disk, or optical data storage device.

[0151] Figure 10 A conceptual partial view of a computer program product provided by an embodiment of the present application is exemplarily shown, where the computer program product includes a computer program for executing a computer process on a computing device.

[0152] In one embodiment, the computer program product is provided using a signal bearing medium 1000. The signal bearing medium 1000 may include one or more program instructions that, when executed by one or more processors, may provide the above-described Figure 2 Thus, for example, reference to Figure 2 In the embodiment shown in , one or more features of S201 to S204 may be undertaken by one or more instructions associated with the signal bearing medium 1000. In addition, Figure 10 The program instructions in also describe example instructions.

[0153] In some examples, the signal-bearing medium 1000 may include a computer-readable medium 1001, such as, but not limited to, a hard drive, a compact disk (CD), a digital video disk (DVD), a digital tape, a memory, a read-only memory (ROM), or a random access memory (RAM), and the like.

[0154] In some implementations, the signal bearing medium 1000 may include a computer recordable medium 1002 such as, but not limited to, a memory, a read / write (R / W) CD, a R / W, a DVD, or the like.

[0155] In some embodiments, signal bearing medium 1000 may include communication medium 1003 such as, but not limited to, digital and / or analog communication media (eg, fiber optic cables, waveguides, wired communication links, wireless communication links, etc.).

[0156] The signal bearing medium 1000 may be conveyed by a wireless form of communication medium 1003. The one or more program instructions may be, for example, computer executable instructions or logic implemented instructions.

[0157] In some examples, such as for Figure 10 The described hydrogen-blended natural gas metering device may be configured to provide various operations, functions, or actions in response to one or more program instructions via computer-readable medium 1001 , computer-recordable medium 1002 , and / or communication medium 1003 .

[0158] Through the description of the above implementation methods, technical personnel in the relevant field can clearly understand that for the convenience and simplicity of description, only the division of the above-mentioned functional modules is used as an example. In actual applications, the above-mentioned functions can be distributed and completed by different functional modules as needed, that is, the internal structure of the device can be divided into different functional modules to complete the full classification or partial functions described above.

[0159] In the several embodiments provided in this application, it should be understood that the disclosed devices and methods can be implemented in other ways. For example, the device embodiments described above are merely schematic. For example, the division of modules or units is only a logical function division. In actual implementation, there may be other division methods, such as multiple units or components can be combined or integrated into another device, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, indirect coupling or communication connection of devices or units, which can be electrical, mechanical or other forms.

[0160] The units described as separate components may or may not be physically separate, and the components shown as units may be one physical unit or multiple physical units, that is, they may be in one location or distributed across multiple locations. Depending on actual needs, some or all of the units may be selected to achieve the purpose of this embodiment.

[0161] In addition, the functional units in the various embodiments of the present application may be integrated into a single processing unit, or each unit may exist physically separately, or two or more units may be integrated into a single unit. The aforementioned integrated units may be implemented in the form of hardware or software functional units.

[0162] If the integrated unit is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a readable storage medium. Based on this understanding, the technical solution of the embodiment of the present application is essentially or the part that contributes to the prior art or the full classification part or part of the technical solution can be embodied in the form of a software product, which is stored in a storage medium and includes several instructions to enable a device (which can be a single-chip microcomputer, chip, etc.) or a processor (processor) to execute the full classification part or part of the steps of the various embodiments of the present application. The aforementioned storage medium includes various media that can store program codes, such as a USB flash drive, a mobile hard disk, a ROM, a RAM, a magnetic disk or an optical disk.

[0163] The above are only specific embodiments of the present application, but the scope of protection of this application is not limited thereto. Any changes or substitutions that can be easily conceived by a person skilled in the art within the technical scope disclosed in this application should be included in the scope of protection of this application. Therefore, the scope of protection of this application should be based on the scope of protection of the claims.

Claims

1. A method for measuring hydrogen-blended natural gas, characterized in that: The method comprises: Determine basic conditions and initial parameters based on the ultrasonic flowmeter's structural parameters, operating parameters, and the gas quality composition of the hydrogen-blended natural gas. The ultrasonic flowmeter's structural parameters include gas applicability range, pipe diameter, roughness, frequency, and signal strength. The operating parameters include pressure, temperature, and apparent flow rate. The gas quality composition of the hydrogen-blended natural gas includes the natural gas composition before hydrogen addition and the hydrogen blending ratio, which indicates the proportion of hydrogen in the gas after hydrogen addition. Based on the basic conditions and the initial parameters, the physical properties of the hydrogen-blended natural gas under the current metering operating condition of the ultrasonic flowmeter are solved based on the hydrogen-blended natural gas state equation, and the internal flow field of the ultrasonic flowmeter is analyzed based on a turbulent flow field distribution model of fluid mechanics to determine the velocity distribution in an axial coordinate system with the pipeline flow direction as the positive direction. The physical properties of the hydrogen-blended natural gas include viscosity, density, and Reynolds number. Based on the velocity distribution in the axial coordinate system, and based on the multi-channel structure and time-difference measurement principle of the ultrasonic flowmeter, the relationship between the time difference of ultrasonic signal propagation in the forward and reverse directions of the gas fluid in the pipeline and the fluid flow velocity is used to solve the cross-sectional flow velocity of the gas pipeline. The effects of different hydrogen doping ratios on gas properties, flow field distribution, and ultrasonic signal propagation are analyzed to predict the measurement error of the ultrasonic flowmeter and its variation pattern. Based on the measurement error of the ultrasonic flowmeter and its variation law, the actual flow rate of the ultrasonic flowmeter under hydrogen doping is predicted according to the data of the hydrogen doping measurement verification of the ultrasonic flowmeter. The data of the hydrogen doping measurement verification of the ultrasonic flowmeter includes the error parameters between the flow rate of the ultrasonic flowmeter and the standard flow rate under different hydrogen doping ratios.

2. The method according to claim 1, characterized in that The method further comprises: Evaluation information is determined based on the actual flow rate and the apparent flow rate, where the evaluation information is used to indicate whether the error parameter meets the process accuracy requirement.

3. The method according to claim 1, characterized in that The method further comprises: A correction coefficient is determined according to the actual flow rate and the indicated flow rate, and the correction coefficient is used to correct the error parameter.

4. The method according to claim 1, wherein The method of predicting the actual flow rate of the ultrasonic flowmeter under hydrogen doping conditions based on the hydrogen doping measurement verification data of the ultrasonic flowmeter includes: In the presence of data on hydrogen doping measurement and calibration of the ultrasonic flowmeter, a deep learning model or a simulation model is used to predict the actual flow rate.

5. The method according to claim 4, characterized in that The method further comprises: In the absence of data on hydrogen doping calibration of the ultrasonic flowmeter, the apparent flow rate, Reynolds number, hydrogen doping ratio, and ultrasonic sound velocity of the ultrasonic flowmeter are selected as four characteristic input parameters, and the actual flow rate is used as the characteristic output parameter. A deep learning model is used for simulation training to finally predict the actual flow rate.

6. The method according to claim 1, characterized in that The ultrasonic flowmeter satisfies the following formula: Where v is the axial flow velocity of the medium or the average velocity on the sound channel line; c is the sound wave transmission velocity of the ultrasonic signal; L is the sound channel length; θ is the angle between the sound channel line and the pipeline axis; t down is the propagation time of the sound wave in the pipeline medium; t up is the countercurrent propagation time of the sound wave in the pipeline medium.

7. The method according to claim 1, characterized in that The state equation of the hydrogen-blended natural gas is the BWRS equation.

8. The method according to claim 1, characterized in that The turbulent flow field distribution model is used to characterize the axial fluid velocity distribution with the pipeline flow direction as the positive direction. The turbulent flow field distribution model satisfies the following formula: Where, u is the velocity; R is the inner diameter of the tube or ultrasonic flowmeter, n is the velocity distribution coefficient, K r is the wall roughness, and Re is the Reynolds number.

9. The method according to claim 1, characterized in that The overall structure of the ultrasonic flowmeter is a pipe covered with a built-in ultrasonic transmitting and receiving probe. The main structural parameters include inner diameter, number of channels, channel angle, channel position, and ultrasonic signal emission intensity. The cross-sectional average flow velocity of the ultrasonic flowmeter is calculated as multi-channel weighted fusion, and the weighted fusion satisfies the following formula: Where V is the average flow velocity in the pipe section, W i is the weighted value of the i-th channel, V i is the average flow velocity of the ith channel, and n is the number of channels of the ultrasonic flowmeter.

10. The method according to claim 1, characterized in that The attenuation model of the change in the synchronous hydrogen doping ratio of the ultrasonic signal in the ultrasonic flowmeter satisfies the following formula: P=P0·e -α·x ; Among them, P is the sound pressure intensity of the sound wave, P0 is the sound pressure intensity at the sound wave transmitting end, α is the sound wave attenuation coefficient, x is the distance from the sound wave transmitting end, w is the angular frequency of the ultrasonic wave, ρ0 is the density, a is the ultrasonic signal propagation speed, u is the viscosity, k is the thermal conductivity, c v 、c p are the heat capacities at constant volume and constant pressure, respectively.

11. A metering device for hydrogen-blended natural gas, characterized in that: include: processor and memory; The processor is coupled to the memory; The memory is used to store one or more programs, and the one or more programs include computer-executable instructions. When the hydrogen-blended natural gas metering device is running, the processor executes the computer-executable instructions stored in the memory to enable the hydrogen-blended natural gas metering device to perform the hydrogen-blended natural gas metering method according to any one of claims 1 to 10.

12. A computer-readable storage medium storing instructions, characterized in that: When a computer executes the instructions, the computer implements the method for metering hydrogen-blended natural gas according to any one of claims 1 to 10.

13. A computer program product, characterized in that The computer program product includes computer program instructions, and when the computer program instructions are executed, the method for metering hydrogen-blended natural gas according to any one of claims 1 to 10 is implemented.

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