The present disclosure generally relates to a standalone gas extraction and detection system comprising a gas extraction chamber operable to receive a wellbore fluid and a carrier gas; a gas detection chamber in fluid communication with the gas extraction chamber, the gas detection chamber comprising reflective surfaces operable to receive infrared radiation (IR) and an extracted gas sample from the gas extraction chamber; an open-path detector operable to detect the IR in the gas detection chamber; and a shaft extending through the gas extraction chamber and the gas detection chamber of the standalone gas extraction and detection system.

An apparatus and method for sensing the amount of a gas in a fluid are disclosed. The apparatus may include a gas sensor, a temperature sensor, a first temperature adjusting unit, or a second temperature adjusting unit. The first and second temperature adjusting units may control the temperature of the gas sensor. The first and second temperature adjusting units may each be used to control the temperature of the gas sensor. According to one technique, they may be used simultaneously to control the temperature of the gas sensor. The temperature sensor may be used to sense the temperature of the gas when it has stabilized to the fluid temperature in which it is being used and the temperature of the gas sensor when it is being controlled by at least one of the first or second temperature adjusting units.

Systems and methods for generating a Methane number for a compressed natural gas fuel by obtaining compositional data from one or more particular analyzers and applying the obtained compositional data to one or more selectable Methane number generation protocols. The systems and methods can include refining of the compressed natural gas fuel to meet a predetermined Methane number.

The present disclosure relates to a simultaneous detection method and system for dissolved gas and partial discharge in insulating oil, and belongs to the field of electrical devices. The method includes the steps: freely diffusing the dissolved gas in the insulating oil to an F-P optical fiber interference cavity through an oil-gas separation membrane; coupling pump light and probe light into the F-P optical fiber interference cavity through a frequency division multiplexer; making, by an optoacoustic effect of the dissolved gas stimulated by the pump light and an ultrasonic wave generated by the partial discharge, the oil-gas separation membrane vibrate; detecting, by the probe light, vibration of the oil-gas separation membrane, which changes a cavity length, wherein when the probe light is reflected by the oil-gas separation membrane, an interference signal is generated due to the change of the cavity length.

An in-situ detection component for dissolved gases in liquid-phase media and preparation method of the in-situ detection component, the detection component is a drilled hollow-core light guiding device coated with a liquid-gas separation membrane on the outer surface. The liquid-gas separation membrane directly filters the gases dissolved in liquid-phase media into the drilled hollow-core light guiding device, where the laser interacts with the gases and generates the response signals that are transmitted through the hollow-core light guiding device, to realize the simultaneous dissolved gas separation and detection. The present application substantially reduces the time required for liquid-gas separation process in detection components, allowing for fast and accurate in-situ detection of dissolved gases, and integration of liquid-gas separation and detection procedures.

An apparatus for measuring dissolved gas includes a body having an internal space, a separator installation part provided in the body and having a separator allowing a dissolved gas to pass therethrough and blocking insulating oil installed therein, and a sensor installation part provided in the body and allowing a gas sensor measuring dissolved gas separated by the separator to be installed therein, wherein the separator installation part and the sensor installation part are configured in such a manner that the separator and the gas sensor are independently installed in the body or separated from the body. According to the apparatus for measuring dissolved gas, a gas sensor may be manufactured to be standardized, and excellent compatibility with respect to various types of gas sensors may be provided.

Disclosed herein are devices and methods for the detection, quantification and/or monitoring of analytes. The systems and methods can be used, for example, to rapidly monitor gases downhole in a well.

An apparatus (1) for detecting gas (4) in a high-voltage device (3) filled with an insulating medium (2) comprises an inlet (5) for introducing a carrier gas (16) and an outlet (6) for discharging a carrier gas (16); at least one gas sensor (12) for detecting a gas (4); a first pump (9) for conveying the carrier gas (16) in the apparatus (1); a membrane (13) which at least consists of at least one semipermeable material, is at least partially surrounded by the insulating medium (2) and is at least partially subjected to a flow of the carrier gas (16); a second pump (10) for conveying the carrier gas (16) into the apparatus (1) and for conveying the carrier gas (16) out of the apparatus (1); wherein there is no valve which can be used to convey the carrier gas (16) into the apparatus (1) or out of the apparatus (1).

A gas monitoring apparatus and system that provides for reliable and accurate monitoring of gaseous hydrogen and other compounds in dielectric oil. The apparatus provides an environment for and is used in conjunction with metal oxide semiconductor sensors. Thermal conditioning zones for oil provide an environment in which variations in oil temperature and ambient temperature are eliminated to insure that analytical data are not affected by these environmental conditions.

Multiphase flowmeters and related methods having asymmetrical flow therethrough are disclosed. An example method includes configuring an inlet manifold, a first flowline, and a second flowline to decrease a gas fraction in a first fluid flow through the first flowline and increase a gas fraction in a second fluid flow through the second flow line; flowing the first fluid flow through the first flowline and flowing the second fluid flow through the second flow line; and determining at least one of 1) a first water liquid ratio of the first fluid flow through the first flowline; 2) a first liquid flow rate of the first fluid flow through the first flow line; or 3) a first gas flow rate of the first fluid flow through the first flow line.