Provided is a downhole tool and a well system. The downhole tool, in one aspect, includes a tubular providing one or more production fluid flow paths for a production fluid. The downhole tool, according to this aspect, further includes one or more float chambers located within the tubular, and two or more floats located within the one or more float chambers. In one aspect, a first of the two or more floats has a first density (.sub.1) between a density of gas (.sub.g) and a density of oil (.sub.o), and a second of the two or more floats has a second density (.sub.2) between the density of oil (.sub.o) and a density of water (.sub.w). The downhole tool, according to this aspect, further includes two or more non-contact proximity sensors configured to sense a radial location of the two or more floats to determine a gas:oil ratio and oil:water ratio.

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.

An apparatus and associated a method are described for performing gas analysis on a gas sample. The method comprising exciting the gas sample with one or more electromagnetic energy sources and obtaining optical absorption signals associated with the gas sample prior to application of a catalytic process to the gas sample as well as during and/or after application of the catalytic process to the gas sample. The obtained optical absorption signals may then be processed using differential calculation approaches to derive information associated with the gas sample, which may include for example information conveying concentrations of certain specific gases in the gas sample. In some implementations, the optical absorption measurement system is configured to use the one or more electromagnetic energy sources to excite the gas sample to produce first optical absorption signals. The optical absorption measurement system is also configured to apply a catalytic process to the gas sample to derive a modified gas sample and to use the one or more electromagnetic energy sources to excite the modified gas sample to produce second optical absorption signals. Information may then be derived at least in part by processing the first optical absorption signals and second optical absorption signals. The apparatus and associated method may find practical uses in a variety of fields including, without being limited to, the field of dissolved gas analysis (DGA) for detecting/monitoring faults in liquid-insulated electrical equipment as well as equipment used for mine safety, particularly coal mines; equipment for analyzing gases that emerge from the bore hole during drilling for natural gas and oil and equipment for identifying gas leaks in underground natural gas lines as well as other areas.

A transformer lifetime evaluation apparatus comprises a first storage part for storing insulation oil used for insulation of a transformer; a second storage part provided to be separated from the first storage part and storing insulation oil which is not used for the insulation of the transformer; a light-emitting unit for emitting light of a specified wavelength; a light-receiving unit for receiving light emitted from the light-emitting unit; a first optical cable connecting the light-emitting unit and the light-receiving unit, providing a moving path of light emitted from the light-emitting unit and received in the light-receiving unit; a second optical cable connecting the light-emitting unit and the light-receiving unit, providing a moving path of light emitted from the light-emitting unit and received in the light-receiving unit; and a calculation part connected to the light-receiving unit and receiving information about an optical property of methanol from the light-receiving unit.

An apparatus and methods for characterizing and communicating carbon dioxide presence in a subterranean formation traversed by a wellbore including collecting fluid from the wellbore at a wellhead, analyzing the fluid for the presence, concentration, or both of the carbon dioxide using an instrument connected to a line collecting the fluid from the wellhead, and communicating the instrument analysis information within 24 hours of analyzing the fluid. Some embodiments may control the introduction of carbon dioxide into the formation. An apparatus and methods for monitoring the presence of carbon dioxide in a fluid produced from a wellbore including continuously collecting and conditioning a sample line from a wellbore, analyzing the sample line with an instrument at the wellsite, recording information from the analyzing continuously over time, and controlling the collecting, conditioning, analyzing, and recording with a process control device.

The present invention provides a transformer malfunction diagnostic device and a malfunction diagnosis method using same, wherein a rule-based learning method is combined with a deep-learning-based learning method based on artificial intelligence. The transformer malfunction diagnosis device according to an embodiment of the present invention comprises: a data scaling unit for scaling dissolved gas analysis data acquired from a transformer, a provisionally labeled data acquisition unit for converting unlabeled data, among the scaled dissolved gas analysis data, to provisionally labeled data and acquiring same; a prelearning unit for performing prelearning for the unlabeled data, among the scaled dissolved gas analysis data, and the provisionally labeled data; and a relearning unit for performing relearning for a labeled data through the transformer of parameters optimized by performing the prelearning.

The invention relates to a method (100) for determining a hydrocarbon-water contact position in a hydrocarbon reservoir, said method comprising the steps of: Providing (110) at least two reservoir fluid samples collected, from connected hydrocarbon reservoir(s), at different known sampling depth values, Measuring (120) abundance of at least one isotope of noble gas from each of the at least two reservoir fluid samples, and Calculating (130) the hydrocarbon-water contact position in the hydrocarbon reservoir from the measured abundances and the known sampling depth values of the at least two reservoir fluid samples.

Certain embodiments of the disclosure relate to a bi-directional oil-flow adapter that is attachable to a valve-controlled port of a transformer housing in which oil is contained for cooling parts of the transformer such as a primary coil and a secondary coil. The bi-directional oil-flow adapter not only allows for an oil sample to be drawn out of the transformer housing via the valve-controlled port but also allows for the oil sample to be used (along with an additional volume of oil if so desired) for flushing the valve-controlled port in order to ensure that a subsequent oil sample is different than a current oil sample. The oil sample can be provided to a dissolved gas analyzer for detecting and analyzing one or more gases that may be present in the oil sample, the one more gases indicative of a level of contamination of the oil sample.

A gas analysis system for analyzing dissolved gas in electrical insulating fluid includes a trap that selectively captures or releases one or more gases, a temperature control device for controlling a temperature of the trap that determining whether the trap is in a gas capture mode or a gas release mode, and a gas sensor for analyzing the gas that was not selectively captured by the trap. The trap may be heated to a first temperature that enables the gas to be adsorbed by the trap, and the trap may be heated to a second temperature that enables the gas to be desorbed by the trap. The gas analysis system may further include a gas flow diverter for directing gas flow past the trap. The captured or released gases may be interfering matrix gases. A method and analyzer for analyzing dissolved gas in an electrical insulating fluid are also disclosed.

An optical sensor for detecting hydrogen in a fluid in physical contact with the sensor is provided. The sensor includes an optical fiber, wherein an end portion of the optical fiber is coated with a multilayer including: a sensing layer, including a film of an alloy, the alloy including Mg, Ni, and M, wherein M is at least one of Zr, Ta, and Hf, and wherein the alloy has the composition Mg.sub.xNi.sub.yM.sub.z, and wherein x is from 40 to 60, y is from 10 to 40, and z is from 10 to 40, and a catalyst layer including Pd. Further, a detection system for hydrogen, including such an optical sensor, and an electrical device having such a detection system are provided.