The present invention is a diagnosis method for internal fault of an oil-immersed electric apparatus using a silicone oil as an insulating oil. The method diagnoses an internal fault of the oil-immersed electric apparatus based on a first concentration ratio that is a concentration ratio between two gases selected from an analysis gas group consisting of hydrogen gas, methane gas, ethane gas, and ethylene gas contained in the, silicone oil, and a second concentration ratio that is a concentration ratio between the other two gases selected from the analysis gas group. A combination of the two gases and a combination of the other two gases are a combination of ethylene gas and hydrogen gas, a combination of ethane gas and hydrogen gas, a combination of ethylene gas and methane gas, or a combination of methane gas and ethane gas.

A measuring rod (1) with a longitudinal axis (A) for insertion in the flow cross section of a tube and for the verification of a flowing medium in this tube having at least one first sender unit (2) for the transmission of a first acoustic or electromagnetic measuring signal (3) and at least one first receiver unit (4) for receiving the first measuring signal, wherein the first sender unit (2) and the first receiver unit (4) define a measuring section, wherein the first sender unit (2) is arranged in such a manner that the first measuring signal (3) crosses the measuring section and wherein the first receiver unit (4) is arranged in such a manner that it, at least during operation without flow, receives the first measuring signal (3) after crossing the measuring section.

A gas-water flash separator system includes an inlet water line fluidly communicable with a sample cylinder containing a pressurized reservoir fluid, and a glass trap sealable with a manifold and in fluid communication with the inlet water line to receive the pressurized reservoir fluid, the pressurized reservoir fluid being separable within the glass trap at atmospheric conditions into a flashed gas and a reservoir water. A gasometer is in fluid communication with the glass trap via a gasometer flow line and operable to receive the flashed gas and measure a volume, a temperature, and a pressure of the flashed gas. A weight and a density of the reservoir water is measured and compared against the volume of the flashed gas to thereby determine a gas-water ratio of the pressurized reservoir fluid.

The method for diagnosing the oil-filled electrical apparatus in the present invention is a method for diagnosing whether or not discharge has occurred inside the oil-filled electrical apparatus. The diagnosing method includes: an in-oil gases analyzing step of analyzing hydrogen gas and a gas selected from the group consisting of methane, ethane, ethylene, acetylene, hydrocarbon having a carbon number of 3 or 4, carbon monoxide, carbon dioxide, oxygen, and nitrogen, contained in an insulating oil used inside the oil-filled electrical apparatus; a step of analyzing a causative substance serving as a cause of generation of hydrogen in the insulating oil irrespective of whether or not the discharge has occurred; and a step of diagnosing whether or not the discharge has occurred based on an analysis result of the in-oil gases analyzing step and an analysis result of the step of analyzing the causative substance.

Methods and apparatus for operating a downhole tool within a wellbore adjacent a subterranean formation to pump contaminated fluid from the formation into the downhole tool while measuring first and second fluid properties of the contaminated fluid. The contaminated fluid comprises native fluid from the formation and a contaminant. The downhole tool is in communication with surface equipment located at surface. The downhole tool and/or surface equipment is operated to estimate a formation volume factor of the contaminated fluid based on at least one of the first and second fluid properties of the contaminated fluid. A linear relationship is then estimated between the first fluid property and a function that relates the first fluid property to the second fluid property and the estimated formation volume factor of the contaminated fluid. A fluid property of the contaminant is then estimated based on the estimated linear relationship.

A temperature estimation method estimating a temperature of a heat generating site in an oil-immersed electric appliance immersed in insulating oil, the insulating oil being silicone oil or ester oil. The temperature estimation method includes measuring concentrations of two types of thermal decomposition products in the insulating oil and calculating a temperature of the heat generating site in the oil-immersed electric appliance based on a concentration ratio between the two types of thermal decomposition products and a relational expression between the temperature of the heat generating site and the concentration ratio prepared in advance. When the silicone oil is adopted as the insulating oil, at least one of the two types of thermal decomposition products is straight-chain siloxane, alcohol containing silicon, or benzene. When the ester oil is adopted as the insulating oil, the two types of thermal decomposition products are fatty acids.

Various embodiments disclosed relate to methods and apparatus for sampling an oil composition. In various embodiments, the present invention provides a method of sampling one or more components of an oil composition. The method includes placing a fluid into a pressure chamber at a first pressure. The pressure chamber includes an oil composition therein. The oil composition contacts the fluid. The fluid includes at least one of a gas, a liquid, and a supercritical fluid. The method also includes taking a sample of at least one of the fluid and the oil composition from the pressure chamber.

An oil void fraction is measured by a simple way. A method of measuring an oil void fraction comprises a step of obtaining each oil void fraction of a plurality of sample oils, the void fraction thereof already-known, that are introduced into a closed space, compressing each sample oil with a predetermined pressure and measuring a volume change of the sample oil when compressed, and obtaining a calibration line for each sample oil, that is a linear function by connecting values represented by a product of the pressure at 0 kPa and the volume change plotted against the pressure when it is compressed to the predetermined pressure, a step of obtaining a value of a test oil sample having an unknown void fraction, that is represented by a product of the pressure at 0 kPa and the volume change plotted against the pressure when it is compressed to the predetermined pressure; and a step of determining the unknown void fraction of the test oil sample by comparing the value of the test sample oil to the calibration line of each sample oil.

A system of spectroscopic devices deployed amongst the fluid infrastructure of hydrocarbon fluids are described herein. The devices provide early visibility into the characteristics of those fluids which inform and educate downstream parties of the potential value of the fluid, or the opportunity to reblend or redirect the fluid to optimize the formulization. By allowing downstream parties to determine the quality and quantity of refined products at an early stage, they are better able to determine the true value of the fluid. The data from the distributed network of spectroscopic analyzers provides valuation information that can be used to make more informed purchasing decisions or allow processors to create blends that optimize the efficiency of refining operations.

A device and associated method can detect hydrocarbon gas with at least a control module having a plurality of different gas detection means housed in a mobile enclosure, the control module configured to activate at least two different gas detection means to provide amounts and types of gases present in a fluid.