Techniques for using data indicating if a gas regulator supplying gas at a regulated pressure to a gas meter (e.g., the gas meter of a house or business) within a gas distribution system has one or more lock-up failure events or venting events, wherein gas is vented to the atmosphere. The data may identify the identity of gas regulators at which the lock-up failure events or venting events occurred. Based at least in part on the identified gas regulators, a number of gas regulators having at least one of lock-up failure events or venting events that are connected to a same gas supply line may be identified. If the number of gas regulators having at least one of lock-up failure events or venting events on the identified gas supply line exceeds a threshold number this may indicate the presence of debris in the gas supply. Remedial steps may be taken, and the situation may be monitored and reassessed.

Geothermal production monitoring systems and related methods are disclosed herein. An example system includes a production well, an injection well, a downhole pump or a downhole compressor to control a production of a multiphase fluid including steam from the production well, a first fluid conduit to transport the multiphase fluid away from the production well, a surface pump disposed downstream of the first fluid conduit, and a second fluid conduit. The surface pump is to inject water into the injection well via the second fluid conduit. A flowmeter is fluidly coupled to the first fluid conduit. The example system includes a processor to control at least one of (a) the downhole pump or the downhole compressor or (b) the surface pump in response to fluid property data generated by the first flowmeter.

Geothermal production monitoring systems and related methods are disclosed herein. An example system includes a production well, an injection well, a downhole pump or a downhole compressor to control a production of a multiphase fluid including steam from the production well, a first fluid conduit to transport the multiphase fluid away from the production well, a surface pump disposed downstream of the first fluid conduit, and a second fluid conduit. The surface pump is to inject water into the injection well via the second fluid conduit. A flowmeter is fluidly coupled to the first fluid conduit. The example system includes a processor to control at least one of (a) the downhole pump or the downhole compressor or (b) the surface pump in response to fluid property data generated by the first flowmeter.

Devices, methods, and systems for operating gas meters are described herein. The systems may include a gas measuring system connectable to a gas line, where the gas measuring system may include a flow rate sensor, a pressure sensor, and a controller in communication with the flow rate sensor and the pressure sensor. The flow rate sensor and the pressure sensor may be configured to sense measures of a gas passing through the gas line. The controller may repeatedly obtain pressure measurements at set pressure measurement times. Measures from the flow sensor may be monitored and when a measure from the flow sensor measure meets a flow rate criteria, the controller may trigger an extra pressure measurement without waiting for a next pressure measurement time. The controller may initiate closing of a gas valve when a measure from the pressure sensor exceeds a threshold value.

Devices, methods, and systems for operating gas meters are described herein. The systems may include a gas meter connectable to a gas line, where the gas meter may have a metrology unit in communication with a flow of gas through the gas line and an index unit in communication with and releasably coupled to the metrology unit. The metrology unit may be configured to generate flow rate data of the flow through the gas line based on outputs from a flow rate sensor, generate gas temperature data based on outputs from a temperature sensor, compensate the flow rate data based on the temperature data, generate an average flow rate, and output the average flow rate data to the index unit. The index unit may generate gas volume data based on flow rate data received from the metrology 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.

A high-performance seafloor flexible oil storage system, solving the existing problems of high storage cost and difficult maintenance of crude oil in offshore oilfields, comprises, sequentially connected, an oil-water separator, a pressure pump, and an input riser extending downward below the sealevel; and a pipeline and multiple flexible oil storage tanks having the same structure with each communicated therewith through a control valve are arranged below the sealevel. One end of the pipeline is communicated with the input riser through a blocking valve and an input valve, and the other end further sequentially connected with an outlet booster pump, an output valve, and an output riser extending upwards above the sealevel and connected to a tanker through a cooler and an output pump. The flexible oil storage tank has a concrete counterweight connected thereunder for fixing it to a seabed. The system has simple structure, convenient maintenance and good practicability.

A high-performance seafloor flexible oil storage system, solving the existing problems of high storage cost and difficult maintenance of crude oil in offshore oilfields, comprises, sequentially connected, an oil-water separator, a pressure pump, and an input riser extending downward below the sealevel; and a pipeline and multiple flexible oil storage tanks having the same structure with each communicated therewith through a control valve are arranged below the sealevel. One end of the pipeline is communicated with the input riser through a blocking valve and an input valve, and the other end further sequentially connected with an outlet booster pump, an output valve, and an output riser extending upwards above the sealevel and connected to a tanker through a cooler and an output pump. The flexible oil storage tank has a concrete counterweight connected thereunder for fixing it to a seabed. The system has simple structure, convenient maintenance and good practicability.

A flow meter system and method measures fluid flow in a conduit. The conduit has a conduit axis. The flow meter includes a sensor configured to provide measurement data relating to the volumetric or mass flowrate though the conduit, and a processor configured to determine flow per unit time in the conduit using the measurement data, an uncertainty measurement per unit time using the measurement data, and an uncertainty quantity using the uncertainty measurement per unit time. The uncertainty quantity is totaled over a time period.