A drawdown compressor assembly for recovering natural gas from a gas line includes a first tubing configured for connection to a first pipe of the gas line at a one end of the first tubing. A compressor is attached to an opposite end of the first tubing and configured to draw natural gas from the first pipe through the first tubing and into the compressor for being compressed by the compressor. A second tubing is connected to the compressor at one end of the second tubing and configured for connection to a second pipe of the gas line at an opposite end of the second tubing. Activation of the compressor draws the natural gas from the first pipe through the first tubing and delivers compressed natural gas to the second pipe through the second tubing.

A system and method for detecting dynamic strain of a housing. The system includes an optical fiber linearly affixed along a surface of a length of the housing and an interrogator comprising a laser source and a photodetector. The optical fiber comprises at least one pair of fiber Bragg gratings (FBGs) tuned to reflect substantially identical wavelengths with a segment of the optical fiber extending between the FBGs. The segment of the optical fiber is linearly affixed along the surface of the housing. The interrogator is configured to perform interferometry by shining laser light along the optical fiber and detecting light reflected by the FBGs. The interrogator outputs dynamic strain measurements based on interferometry performed on the reflected light.

A system and method for detecting dynamic strain of a housing. The system includes an optical fiber linearly affixed along a surface of a length of the housing and an interrogator comprising a laser source and a photodetector. The optical fiber comprises at least one pair of fiber Bragg gratings (FBGs) tuned to reflect substantially identical wavelengths with a segment of the optical fiber extending between the FBGs. The segment of the optical fiber is linearly affixed along the surface of the housing. The interrogator is configured to perform interferometry by shining laser light along the optical fiber and detecting light reflected by the FBGs. The interrogator outputs dynamic strain measurements based on interferometry performed on the reflected light.

The present disclosure provides a method for smart gas terminal management, an Internet of Things system, and a medium thereof. The method is performed by a smart gas device management platform of the Internet of Things system for smart gas terminal management. The method comprises: obtaining user data authorized for usage by a user, wherein the user data includes at least one of gas information, water usage information, electricity usage information, and network information; determining, based on the user data, residence information of the user; and determining, based on the residence information, a smart gas terminal management solution.

The embodiments of the present disclosure provide methods for assessing electrochemical corrosion of a smart gas pipeline. The method may be implemented based on a smart gas pipeline network safety management platform of an Internet of Things system for assessing electrochemical corrosion of a smart gas pipeline. The method may include: obtaining environmental data of at least one position of a gas pipeline at a first time; determining an electrochemical corrosion degree of each of the at least one position of the gas pipeline at a second time based on the environmental data of the at least one position at the first time, wherein the first time is before the second time; determining, based on electrochemical corrosion degree, a protection scheme of the gas pipeline.

Superterranean acoustic networks, methods of forming superterranean acoustic networks, and methods of operating superterranean acoustic networks are disclosed herein. The superterranean acoustic networks include superterranean hydrocarbon infrastructure that extends above a ground surface, defines a waveguide, and contains a fluid. The infrastructure also includes a plurality of acoustic communication nodes spaced-apart along the superterranean hydrocarbon infrastructure. Each acoustic communication node of the plurality of acoustic communication nodes includes an acoustic transmitter and an acoustic receiver. The acoustic transmitter is configured to generate a generated acoustic signal and to supply the generated acoustic signal to the waveguide. Responsive to receipt of the generated acoustic signal, the waveguide is configured to propagate a propagated acoustic signal there through. The acoustic receiver is configured to receive another propagated acoustic signal, which is generated by another acoustic communication node of the plurality of acoustic communication nodes, from the waveguide as a received acoustic signal.

An infrastructure monitoring assembly includes a nozzle cap defining an internal cavity; an antenna positioned at least partially external to the internal cavity; and the antenna covered with a non-metallic material. An infrastructure monitoring assembly includes a nozzle cap defining a first end and a second end, the first end defining a threaded bore configured to mount on a nozzle of a fire hydrant; a cover coupled to the nozzle cap opposite from the first end; an enclosure positioned at least partially between the cover and the first end, the enclosure at least partially defining a cavity; a monitoring device positioned within the cavity; and an antenna positioned between the cover and the first end of the nozzle cap, the antenna connected in electrical communication with the monitoring device, the antenna covered by a non-metallic material.

An infrastructure monitoring assembly includes a nozzle cap defining an internal cavity; an antenna positioned at least partially external to the internal cavity; and the antenna covered with a non-metallic material. An infrastructure monitoring assembly includes a nozzle cap defining a first end and a second end, the first end defining a threaded bore configured to mount on a nozzle of a fire hydrant; a cover coupled to the nozzle cap opposite from the first end; an enclosure positioned at least partially between the cover and the first end, the enclosure at least partially defining a cavity; a monitoring device positioned within the cavity; and an antenna positioned between the cover and the first end of the nozzle cap, the antenna connected in electrical communication with the monitoring device, the antenna covered by a non-metallic material.

An inhibitor injection spool is provided. The spool includes a segment of pipeline configured to convey crude oil and to couple with a pipeline system conveying crude oil. The spool also includes a valve on a top side or an underside of the segment of pipeline such that an interior of the segment of pipeline is selectively accessible from an exterior of the segment of pipeline. A solid corrosion inhibitor is configured to traverse an interior of the valve and such that it is positioned within the interior of the segment of pipeline such that at least a portion of the solid corrosion inhibitor fluidly contacts the crude oil traversing the segment of pipeline. Two mesh screens are coupled to the interior of the segment of pipeline such that crude oil traversing the segment of pipeline may not bypass either the first or second mesh screens.

A system for forecasting leaks in a fluid-delivery pipeline network. The system identifies a subsystem in the pipeline network that comprises a plurality of topologically connected stations. The system accesses historical temporal sensor measurements of a plurality of variables of the stations that are directly connected and generates a temporal causal dependency model for a first control variable at the first station in the subsystem, based on the plurality of time series of sensor measurements of a second variable of the first station, and temporal delay characteristics of the plurality of time series of sensor measurements of the second variable at the stations directly connected to the first station. The system automatically calculates a normal operating value of the first control variable at the first station and the deviations between actual measured values and the normal operating value and determines a threshold deviation that indicates a leak event.