Systems and methods presented herein generally relate to a tool for determining a refractive index of a formation fluid using attenuated total reflection. The tool includes a body having a fluid admitting assembly and a flow line that receives the formation fluid. The tool also includes two different crystals having faces in contact with fluid in the flow line. The tool further includes at least one light source coupled to the crystals and configured to direct light into the crystals. In addition, the wavelength, the refractive indices, and the angles of incidence are configured such that the light undergoes total internal reflection at interfaces between the crystals and the formation fluid. The tool also includes at least one light detector coupled to the crystals and configured to measure reflected light exiting the crystals. The tool further includes at least one processor coupled to the at least one light detector.

A method analyses a gas dissolved in an insulating medium of a high-voltage device. The method includes: transferring the dissolved gas by an analysis device into a gas phase to obtain an analysis gas mixture; transporting the analysis gas mixture to an analysis sensor of the analysis device; generating a sensor signal as an output signal of the analysis sensor as a function of a composition of the analysis gas mixture; determining a first intermediate value based on the sensor signal and at least one disturbance value; determining a second intermediate value based on the first intermediate value and at least one specific value of the analysis device; and determining a value for a concentration of the dissolved gas in the insulating medium based on the second intermediate value.

A system for enhancing oilfield performance analysis and optimization, comprising a data collection module configured to collect real-time Gas-Oil Ratio (GOR) and Water Cut (WC) data from oilfield sensors a physics-based modeling module configured to simulate a vertical pressure profile based on the collected GOR and WC data, and a machine learning module configured to analyze outputs from the physics-based modeling module and historical data, classify wells based on the analysis, establish baseline metrics for evaluating reservoir productivity based on the analysis and classification, generate a recommendation for well operations based on the analysis, classification and baseline metrics, and a user interface configured to display the recommendation.

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 hydraulic dissolved air measurement system and method are described that include a testing device, a pressure sensor, a piston actuation device, and a controller. The testing device includes a housing and a movable piston that define a measurement chamber configured to receive a hydraulic fluid sample from a hydraulic reservoir. The controller controls the piston actuation device to move the piston to expand the measurement chamber to an expanded state after the hydraulic fluid sample is received in the measurement chamber. The controller determines a volume change value that represents a volume increase of the measurement chamber based on the movement of the piston. The controller receives a pressure value from the pressure sensor that represents the pressure within the measurement chamber in the expanded state, and determines a dissolved air content of the hydraulic fluid sample based on the pressure value and the volume change value.

A monitoring system for a piece of electrical equipment having components immersed in electrical insulating liquid, associated methods and uses thereof are described. The monitoring system includes alert threshold determination capabilities. The monitoring system may comprise: an analysis system configured for obtaining measurements conveying concentrations of dissolved molecular species in the electrical insulating liquid; and a processing system programmed for: processing the measurements conveying concentrations of dissolved molecular species and one or more alert thresholds to determine if a predetermined condition corresponding to the one or more alert thresholds is met; causing an alert event in response to the predetermined condition being met; and performing a threshold adjustment determination process to derive new values for the one or more alert thresholds at least in part by processing historical measurements of concentrations of dissolved molecular species. Alternate embodiments may make use of an artificial intelligence engine trained using historical concentration measurements to process the measurements conveying concentrations of dissolved molecular species to adjust alarm thresholds.

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.

A system for enhancing oilfield performance analysis and optimization, comprising a data collection module configured to collect real-time Gas-Oil Ratio (GOR) and Water Cut (WC) data from oilfield sensors a physics-based modeling module configured to simulate a vertical pressure profile based on the collected GOR and WC data, and a machine learning module configured to analyze outputs from the physics-based modeling module and historical data, classify wells based on the analysis, establish baseline metrics for evaluating reservoir productivity based on the analysis and classification, generate a recommendation for well operations based on the analysis, classification and baseline metrics, and a user interface configured to display the recommendation.

A method for estimating a quantity of natural hydrogen in a subterranean formation includes degassing drilling fluid obtained from a wellbore to obtain a gas sample including a quantity of hydrogen gas, measuring a concentration of hydrogen in the gas sample, and applying a correction to the measured concentration of hydrogen to estimate the quantity of natural hydrogen in the subterranean formation.

Systems and methods of the present disclosure include a fluid sampling system that includes a fluid sampling tool and a controller. The fluid sampling tool includes a probe configured to draw a fluid from a formation within which the fluid sampling tool is disposed during an oil and gas well operation. The fluid sampling tool also includes a spectrometer configured to detect raw data relating to optical properties of the fluid. The raw data relating to the optical properties of the fluid includes optical absorbance at a plurality of wavelengths. The controller includes at least one processor configured to execute coded instructions stored in memory of the controller, wherein the coded instructions, when executed by the at least one processor, cause the processor to receive the raw data relating to the optical properties of the fluid from the spectrometer, and to predict percentage levels of one or more components in the fluid based at least in part on the raw data relating to the optical properties of the fluid. The one or more components comprise at least one gas component without an optical signature in the near infrared spectrum.