A system, comprising at least one source for irradiating electromagnetic radiation into a sample fluid and a reference fluid resulting in a change in a temperature of the sample fluid and a change in a temperature of the reference fluid, and a processing subsystem that monitors and determines a concentration of a gas of interest dissolved in the sample fluid based upon a difference between the change in the temperature of the sample fluid and the change in the temperature of the reference fluid, wherein the reference fluid does not contain the gas of interest, and the electromagnetic radiation has a wavelength range corresponding to a spectral absorption range of the gas of interest.

A method for accurately diagnosing an internal fault of an oil-immersed transformer by analyzing content ratios of dissolved gases generated when the internal fault occurs in the oil-immersed transformer is provided. The method diagnoses the internal fault by analyzing the dissolved gases contained in the insulating oil of the oil-immersed transformer for internal fault diagnosis, wherein the method comprises: a first step of extracting H2, CH4, C2H4, and C2H2 from the dissolved gases; a second step of calculating a content ratio (%) of each dissolved gas from the total content of the four dissolved gases selected from the extracted five dissolved gases; and a third step of determining the internal fault of the oil-immersed transformer for diagnosis corresponding to an internal fault region according to content ratio (%) values of the calculated four dissolved gases and predetermined content ratios (%) of the four dissolved gases.

A method measures electrical equipment of a system for supplying power. The electrical equipment includes a housing with an insulating fluid. The method includes: recording measurement values representing dissolved gases in the insulating fluid; determining equipment parameters; adapting the measurement values to a uniform evaluation basis using the equipment parameters; assessing a state of the electrical equipment based on the adapted measurement values at least one machine learning method; and outputting the state.

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 is an experimental device and method for solubility determination of methane in oil-based drilling fluid, comprising a pressure-resistant gas chamber and an equilibrium still both arranged in a constant-temperature oil bath heating oven, a gas booster pump, and a vacuum system used for vacuuming the pressure-resistant gas chamber and the equilibrium still, and a data acquisition device for collecting temperature and pressure signals; the gas booster pump is connected to drive air source inlet, a gas check valve is arranged on the pipe between the pressure-resistant gas chamber and the gas booster pump that is also connected with a high-pressure gas cylinder, the equilibrium still is divided into a dissolution equilibrium chamber at the top and a hydraulic oil chamber at the bottom by a high-pressure dynamic seal structure, the dissolution equilibrium chamber is connected to a liquid inlet funnel through the fourth globe valve.

Methods and systems for determining an estimated reservoir property using a determined desorption stage are disclosed. The method includes determining a fluid property and composition of a first fluid sample obtained from a reservoir, determining a measured relative volume of gas components and isotope ratios of gas components of the sample, and determining an equation of state. The method also includes obtaining a second and third sample at two later times, determining a composition, a measured relative volume of gas components, and isotope ratios of gas components of the later samples, and calibrating the equation of state utilizing the fluid composition and measured relative volume of gas components. The method further includes predicting a relative volume of gas components from the equation of state, determining a desorption stage, determining a critical pressure, an extent of desorption and a quantity of produced desorbed gas and determining the estimated reservoir property.

Embodiments herein relate to systems for detecting air bubbles in fluids. In an embodiment, a fluid system aeration detector is included having an optical air bubble sensor. The optical air bubble sensor can include a light source, a light detector, and a sensor controller. The sensor controller can be in signal communication with the light detector and can be configured to detect air bubbles based on the signals received from the light detector. The sensor controller can further be configured to estimate an amount of aeration of a fluid based on the detected air bubbles. Other embodiments are also included herein.

A system for gas analysis is provided. The system includes a gas extraction assembly having an extraction chamber having an upper end, a lower end, and an interior space. The gas extraction assembly further having one or more retainers positioned within the interior space of the extraction chamber. The gas extraction assembly further having gas permeable membrane retained within the interior space of the extraction chamber by the one or more retainers, the gas permeable membrane disposed in S-shaped curves extending from adjacent the upper end to adjacent the lower end within the interior space of the extraction chamber.

A method and a system for optimization of development by carbon dioxide injection based on incomplete miscibility characteristics are provided, where the method includes following steps: building a three-dimensional reservoir model based on laboratory experiments and reservoir values, where the three-dimensional reservoir model includes: a fluid model and a reservoir model; based on the three-dimensional reservoir model, obtaining incomplete miscibility characteristics of reservoir development by carbon dioxide injection; and completing whole life cycle optimization development of carbon dioxide injection based on the incomplete miscibility characteristics.

A method of detecting an increase in gas content in a pipe. The method includes flowing fluid through the pipe. The method includes generating, by a network analyzer, microwaves data representing a complex scattering coefficient over a first spectrum of microwave frequencies that are emitted through a waveguide and a fluid within the pipe and determining a statistical profile of a complex scattering magnitude over a second spectrum of microwave frequencies. The method includes determining that an amount of gas within the pipe satisfies a threshold amount and causing a flow of fluids within the pipe to slow or stop until the amount of gas falls below a predetermined threshold value.