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.

System and methods for analyzing a multiphase production fluid include a fluidic supply and analysis unit configured to transition the fluidic separation chamber to a static state after a complete gaseous phase column and a complete oil phase column are formed within the fluidic separation chamber; communicate with the fluidic separation detector to measure the absolute or relative sizes of the complete gaseous phase column and the complete oil phase column; and calculate an oil/gas volume fraction as a function of the measured sizes of the gaseous phase and oil phase columns in the fluidic separation chamber.

System and methods for analyzing a multiphase production fluid include a fluidic supply and analysis unit configured to transition the fluidic separation chamber to a static state after a complete gaseous phase column and a complete oil phase column are formed within the fluidic separation chamber; communicate with the fluidic separation detector to measure the absolute or relative sizes of the complete gaseous phase column and the complete oil phase column; and calculate an oil/gas volume fraction as a function of the measured sizes of the gaseous phase and oil phase columns in the fluidic separation chamber.

A control system having a primary run and a trim run, each run including an inlet coupled to a main gas supply line, a pneumatically actuated control valve positioned downstream of the inlet, a pneumatic pressure controller having variable deadband adjustment, and an outlet feeding into a gas supply line to the facility. The control valve of the primary run is preferably high-capacity, while the control valve of the trim run is low-capacity. Further, the system and method for controlling gas supply to the facility has a total flow capacity through the primary run and trim run to the facility being defined by C.sub.X, which is the total flow capacity of the primary run (C.sub.P) plus the total flow capacity of the trim run (C.sub.T), and an actual gas flow to the facility being defined by F.sub.X, which is the actual flow of the primary run (F.sub.P) plus the actual flow of the trim run (F.sub.T) and wherein F.sub.X is less than C.sub.X, C.sub.T is less than C.sub.P and F.sub.X is either stable, increasing, or decreasing based on a demand from the facility.

A control system having a primary run and a trim run, each run including an inlet coupled to a main gas supply line, a pneumatically actuated control valve positioned downstream of the inlet, a pneumatic pressure controller having variable deadband adjustment, and an outlet feeding into a gas supply line to the facility. The control valve of the primary run is preferably high-capacity, while the control valve of the trim run is low-capacity. Further, the system and method for controlling gas supply to the facility has a total flow capacity through the primary run and trim run to the facility being defined by C.sub.X, which is the total flow capacity of the primary run (C.sub.P) plus the total flow capacity of the trim run (C.sub.T), and an actual gas flow to the facility being defined by F.sub.X, which is the actual flow of the primary run (F.sub.P) plus the actual flow of the trim run (F.sub.T) and wherein F.sub.X is less than C.sub.X, C.sub.T is less than C.sub.P and F.sub.X is either stable, increasing, or decreasing based on a demand from the facility.

A system, method and apparatus to transport and distribute hydrogen, store energy at scale, and interconnect locations where large quantities of “green” hydrogen can be produced most advantageously, with cities, towns and rural communities where hydrogen is needed as a clean transportation fuel, industrial feedstock, power source, and for long-term storage of electrical power. A hydrogen distribution pipeline enables use of natural gas, oil and other existing pipelines to transport hydrogen to one or more distribution points; and in one embodiment, integrates a lighter-than-air airship to transport hydrogen between locations where pipelines don't exist or are impractical. The disclosed hydrogen distribution pipeline also enables use of water, sewer, storm drain and other existing pipelines for local distribution, thereby saving time and money, and reducing construction disruption to the local community, in establishing these infrastructure components necessary to the widespread use of hydrogen in helping address climate change.

A system, method and apparatus to transport and distribute hydrogen, store energy at scale, and interconnect locations where large quantities of “green” hydrogen can be produced most advantageously, with cities, towns and rural communities where hydrogen is needed as a clean transportation fuel, industrial feedstock, power source, and for long-term storage of electrical power. A hydrogen distribution pipeline enables use of natural gas, oil and other existing pipelines to transport hydrogen to one or more distribution points; and in one embodiment, integrates a lighter-than-air airship to transport hydrogen between locations where pipelines don't exist or are impractical. The disclosed hydrogen distribution pipeline also enables use of water, sewer, storm drain and other existing pipelines for local distribution, thereby saving time and money, and reducing construction disruption to the local community, in establishing these infrastructure components necessary to the widespread use of hydrogen in helping address climate change.

Method and system for storing natural gas and natural gas liquids via a variable volume flow splitter from a producing field. A method and system comprising storing natural gas and natural gas liquids while simultaneously selling natural gas and natural gas liquids from a single compressor in quantities as deemed desirable. In response to desired quantities to be injected into a storage reservoir or sold, the system provides a single action (e.g., a single action such as the click of a mouse button) that splits the gas stream into injection for storage and the sales pipeline for transportation to market by adjusting a flow splitter of a single value or valves in combination operated remotely or manually on the downstream side of the sales gas compressor that varies the volume to any combination and ratio from 0 to 100% of gas and entrained gas liquids to be sold or injected.

A sensor device determines measured values of a property of a fluid, in particular of a gas, in a cavity of a gas turbine engine having a duct for carrying the fluid from the cavity to a sensor element. A data processing device is coupled to the sensor element and processes the measured values. The data processing device has a device for detecting changes in the measured values with respect to time, and an evaluation device, by which the changes in the measured values with respect to time can be detected. If there is a deviation in the changes in the measured values with respect to time from a predefined criterion, a signal relating to an at least partial blockage of the at least one inlet duct can be output. A measurement method is also disclosed.