A metering method based on converted slip ratio fitting for wet natural gas is provided. The method includes fitting relationships between a gas Froude number and Venturi differential pressure and Venturi pressure loss with known data to obtain a gas Froude number calculation formula; dividing the known data according to a size of the gas Froude number, and performing piecewise fitting to obtain a piecewise converted slip ratio calculation formula under different gas Froude numbers; performing fitting on the dryness fraction and the converted slip ratio calculation formula; and acquiring, on the basis of the gas Froude number calculation formula, the converted slip ratio calculation formula, an overrated factor calculation formula and a dryness fraction calculation formula, some necessary real-time data to calculate a real-time flow rate of the wet gas. The method avoids using a ray flow meter and has advantages that include accurate metering and no radioactive pollution.

A metering method based on converted slip ratio fitting for wet natural gas is provided. The method includes fitting relationships between a gas Froude number and Venturi differential pressure and Venturi pressure loss with known data to obtain a gas Froude number calculation formula; dividing the known data according to a size of the gas Froude number, and performing piecewise fitting to obtain a piecewise converted slip ratio calculation formula under different gas Froude numbers; performing fitting on the dryness fraction and the converted slip ratio calculation formula; and acquiring, on the basis of the gas Froude number calculation formula, the converted slip ratio calculation formula, an overrated factor calculation formula and a dryness fraction calculation formula, some necessary real-time data to calculate a real-time flow rate of the wet gas. The method avoids using a ray flow meter and has advantages that include accurate metering and no radioactive pollution.

System and methods for analyzing a multiphase production fluid, calculating production fluid phase flow rates, and calculating an oil/gas and oil/gas/water volume fractions of the multiphase production fluid, are provided. Contemplated systems and method may utilize fluidic piping, a production fluid supply valve, a fluidic separation chamber, an inert gas exhaust valve, a separation chamber pressure sensor, a fluidic separation detector, and a fluidic supply and analysis unit.

System and methods for analyzing a multiphase production fluid, calculating production fluid phase flow rates, and calculating an oil/gas and oil/gas/water volume fractions of the multiphase production fluid, are provided. Contemplated systems and method may utilize fluidic piping, a production fluid supply valve, a fluidic separation chamber, an inert gas exhaust valve, a separation chamber pressure sensor, a fluidic separation detector, and a fluidic supply and analysis unit.

A system and method for transporting and distributing hydrogen, reducing the risk of hydrogen leakage, maintaining a record of provenance, and measuring and recording its purity level as it flows from source to destination to assure it complies with a predetermined range of values. The system includes a hydrogen delivery line made from metallic or non-metallic pipe that may be placed inside a safety pipe such that a channel is formed between an exterior of the hydrogen delivery line and an interior of the safety pipe. A sweeper gas or liquid may be injected into the channel to purge any hydrogen that might escape from the hydrogen delivery line, and one or more sensors may be used to detect and avoid the presence of an unacceptable level of hydrogen, or to stop the flow of hydrogen and remediate the problem well before a safety or environmental risk can occur.

A system and method for transporting and distributing hydrogen, reducing the risk of hydrogen leakage, maintaining a record of provenance, and measuring and recording its purity level as it flows from source to destination to assure it complies with a predetermined range of values. The system includes a hydrogen delivery line made from metallic or non-metallic pipe that may be placed inside a safety pipe such that a channel is formed between an exterior of the hydrogen delivery line and an interior of the safety pipe. A sweeper gas or liquid may be injected into the channel to purge any hydrogen that might escape from the hydrogen delivery line, and one or more sensors may be used to detect and avoid the presence of an unacceptable level of hydrogen, or to stop the flow of hydrogen and remediate the problem well before a safety or environmental risk can occur.

The embodiments of present disclosure provide a method for processing abnormality of a smart gas pipeline network implemented based on a smart gas safety management platform of a safety management Internet of Things (IoT) system for the smart gas pipeline network. The method may include: obtaining detection information of a gas pipeline in a target area; determining an abnormal pipeline in the target area based on the detection information; and determining an abnormality handling scheme based on the detection information corresponding to the abnormal pipeline.

The embodiments of present disclosure provide a method for processing abnormality of a smart gas pipeline network implemented based on a smart gas safety management platform of a safety management Internet of Things (IoT) system for the smart gas pipeline network. The method may include: obtaining detection information of a gas pipeline in a target area; determining an abnormal pipeline in the target area based on the detection information; and determining an abnormality handling scheme based on the detection information corresponding to the abnormal pipeline.

Embodiments of the invention provide an electric heat trace (EHT) control system for use with a piping system having pipes and capable of transporting a fluid. The EHT control system includes an EHT circuit for heating the piping system, a temperature sensor outputting a temperature value, a flow status sensor outputting a flow status value, and an EHT management system. The EHT management system can include a controller connected to the EHT circuit in order to selectively energize the EHT circuit. The controller can be connected to the temperature sensor in order to receive the temperature value and the flow status sensor in order to receive the flow status value. The controller can be configured to execute an EHT management program including the steps of receiving the temperature value, receiving the flow status value, and utilizing the temperature value and/or the flow status value to determine whether or not to energize the EHT circuit.

Embodiments of the invention provide an electric heat trace (EHT) control system for use with a piping system having pipes and capable of transporting a fluid. The EHT control system includes an EHT circuit for heating the piping system, a temperature sensor outputting a temperature value, a flow status sensor outputting a flow status value, and an EHT management system. The EHT management system can include a controller connected to the EHT circuit in order to selectively energize the EHT circuit. The controller can be connected to the temperature sensor in order to receive the temperature value and the flow status sensor in order to receive the flow status value. The controller can be configured to execute an EHT management program including the steps of receiving the temperature value, receiving the flow status value, and utilizing the temperature value and/or the flow status value to determine whether or not to energize the EHT circuit.