A system uses existing pipelines, e.g., natural gas, oil, etc., to transport hydrogen to one or more distribution points. The disclosed hydrogen distribution system enables use of water, sewer, storm drain and other existing pipelines for local distribution. Hydrogen is produced from an energy source at a producing location. A safety pipe is located inside an existing pipeline configured to carry a first product and a hydrogen delivery line, configured to carry hydrogen, is placed inside the safety pipe such that a channel is formed between an exterior of the hydrogen delivery line and an interior of the safety pipe. Hydrogen is injected into the hydrogen delivery line and a sweeper gas is injected into the channel to purge any hydrogen that might be leaking from the hydrogen delivery line.

Disclosed are a method and a device for measuring a flux of a heavy oil-miscible phase fluid, the method including: flowing of the heavy oil-miscible phase fluid out of an oil and gas well through the pipeline, with the heavy oil-miscible phase fluid including at least two fluid media; measuring a total flux of throttling differential pressure of the heavy oil-miscible phase fluid flowing through the streamlined spindle; carrying out a measurement with a light quantum of at least four levels on the heavy oil-miscible phase fluid by the phase separator with light quantum of multi levels, such that a linear mass of each of the at least two fluid media is obtained; and obtaining a flux of each of the at least two fluid media from the total flux of throttling differential pressure and the linear mass of each of the at least two fluid media.

Disclosed are a method and a device for measuring a flux of a heavy oil-miscible phase fluid, the method including: flowing of the heavy oil-miscible phase fluid out of an oil and gas well through the pipeline, with the heavy oil-miscible phase fluid including at least two fluid media; measuring a total flux of throttling differential pressure of the heavy oil-miscible phase fluid flowing through the streamlined spindle; carrying out a measurement with a light quantum of at least four levels on the heavy oil-miscible phase fluid by the phase separator with light quantum of multi levels, such that a linear mass of each of the at least two fluid media is obtained; and obtaining a flux of each of the at least two fluid media from the total flux of throttling differential pressure and the linear mass of each of the at least two fluid media.

A static mixer for mixing fluid flow in a pipeline includes a body having a plurality of slots through the body, the slots being angled with respect to an axis passing through a center of the body. A plurality of arms extends from an outer edge of the body towards a center of the body, each arm having a flat surface on a first side of the body and angled sides along at least a portion thereof extending to a second side of the body. The plurality of slots includes at least one concentric ring of slots.

In some configurations, a supply-chain characteristic-vectors merchandising system and a method for an environmental characteristic-vectors of a gas communicating from an upstream amenity to a downstream amenity in a supply-chain may be disclosed. The system may be configured to track oil and/or gas throughout the supply-chain by associating characteristic-vectors (e.g., environmental, operational, physical etc.) of the upstream amenity and the downstream amenity with the energy units of the gas transmitted through the supply-chain.

In some configurations, a supply-chain characteristic-vectors merchandising system and a method for an environmental characteristic-vectors of a gas communicating from an upstream amenity to a downstream amenity in a supply-chain may be disclosed. The system may be configured to track oil and/or gas throughout the supply-chain by associating characteristic-vectors (e.g., environmental, operational, physical etc.) of the upstream amenity and the downstream amenity with the energy units of the gas transmitted through the supply-chain.

A management system for managing an operating condition for a pipeline that processes fluid, the management system including a processor configured to: obtain measurement values from sensors provided in devices that constitute the pipeline; and estimate a maximum processing amount of the fluid in the entire pipeline in operation by inputting the measurement values obtained from the sensors into a physical model that is built based on physical properties of the devices.

A management system for managing an operating condition for a pipeline that processes fluid, the management system including a processor configured to: obtain measurement values from sensors provided in devices that constitute the pipeline; and estimate a maximum processing amount of the fluid in the entire pipeline in operation by inputting the measurement values obtained from the sensors into a physical model that is built based on physical properties of the devices.

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.