A system and method for evaluating power transformers is disclosed. The method includes the steps of acquiring data representing one or more parameters of a power transformer, using rules to derive one or more broad physical conditions of the power transformer from the acquired data, and using the broad physical conditions as inputs to compute a plurality of indices. Each index represents a category of failure mechanisms of the power transformer. The method further includes the steps of using the plurality of indices to determine a corrective action and performing the corrective action on the power transformer.

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, andCalculating (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.

Systems and methods include techniques for using smart polymers. Units of smart polymers with hydrogen sulfide (H2S) sensitivity are inserted by a monitoring system into drilling fluid pumped into a well. The smart polymers are configured to be triggered by increasing H2S concentrations. An insertion timestamp associated with each unit is stored. Each insertion timestamp indicates a time that each unit was inserted. Continuous images and observed characteristics of returning mud exiting through an annulus of the well and containing the units of smart polymer are captured by a camera positioned at a sensing location and linked to the monitoring system. An estimate of H2S levels at a drill bit of the drilling operation is determined using continuous images, observed characteristics, and insertion timestamps, and based at least in part on executing image processing algorithms, machine-learning models, and deep-learning models. Changes to drilling parameters are suggested.

Disclosed herein are systems, methods, and computer-readable media for utilizing sensor data captured by one or more sensors as well as ground-truth physically sampled data to generate a predictive model that can be used to estimate a measurable parameter without having to obtain additional physically sampled data for the parameter.

An electric transformer is provided. The electric transformer includes an electric transformer main body and a heat radiating portion including a pipe configured to introduce an insulating oil into the electric transformer main body so as to absorb heat generated from the electric transformer main body, and the pipe is provided with a fixing member to which a sensing member is coupled such that the sensing member is exposed to the inside of the pipe so as to detect a dissolved gas in the insulating oil.

The present application discloses a gas logging system, including a degasser configured to degas a sample to separate a gas to be tested; and a detector connected to the degasser and configured to receive the gas to be tested separated by the degasser and perform detection, where the degasser comprises a degassing cover, the degassing cover includes a spherical crown disk surface and a plurality of semipermeable membrane degassing units on the spherical crown disk surface, wherein the plurality of semipermeable membrane degassing units are arranged on the spherical crown disk surface according to the Fibonacci Spiral Rule. The gas logging system provided by the present application may improve the distribution uniformity of a drilling fluid on the degassing cover while increasing arrangement number, and reduce the impact on semipermeable membrane degassing units.

A crude oil composition estimation method estimates a composition of crude oil for use in simulation of a material balance in an absorption and liquefaction system that absorbs vapors emitted from the crude oil with the crude oil. The crude oil composition estimation method includes: comparing a calculated concentration of a treated gas with a measured concentration of the treated gas; estimating, when the calculated concentration agrees with the measured concentration, that the concentration included in the crude oil is a correct crude oil composition; and repeating, when the calculated concentration does not agree with the measured concentration, a process of correcting the concentration included in the crude oil and then comparing the calculated concentration with the measured concentration, until the calculated concentration agrees with the measured concentration, and when they agree, estimating that the corrected concentration in the crude oil is a correct crude oil composition.

A method includes identifying linearly behaving data within obtained data associated with fluid obtained from a subterranean formation. Shrinkage factor is determined based on the linearly behaving data. A function relating GOR data of the obtained fluid with the determined shrinkage factor is determined. A first linear relationship between optical density (OD) data of the obtained fluid and the function is determined. A second linear relationship between density data of the obtained fluid and the function is determined. An oil-based mud (OBM) filtrate contamination property of OBM filtrate within the obtained fluid based on the first linear relationship is determined. A native formation property of native formation fluid within the obtained fluid based on the second linear relationship is determined. A volume fraction of OBM filtrate contamination within the obtained fluid based on the OBM filtrate contamination property and the native formation property is estimated.

The present invention is directed to a method of estimating an overheating temperature of an oil-immersed electric appliance in which ester oil is used as insulating oil. The overheating temperature is estimated based on a first concentration ratio representing a concentration ratio between two types of gas components contained in the ester oil and a second concentration ratio representing a concentration ratio between other two types of gas components contained in the ester oil. The first concentration ratio and the second concentration ratio are selected from a concentration ratio between acetylene and ethane, a concentration ratio between acetylene and hydrogen, a concentration ratio between acetylene and methane, and a concentration ratio between acetylene and ethylene.

An apparatus to detect contaminants in a fuel comprises an input to receive a fuel flow. A light scattering system is coupled to the input. An imaging system is coupled to the light scattering system. A memory is coupled to the imaging system. A processor is coupled to the memory. Output signals from the imaging and light scattering systems are transferred to the processor. The processor is configured to cause the light scattering system to monitor the light scattering intensity from the contaminants in the fuel flow. The processor is configured to cause the light scattering system to measure a light scattering intensity signal from the contaminants in the fuel flow. The processor is configured to generate a trigger signal to turn on the imaging system when the light scattering intensity is greater than a predetermined threshold.