A fast response fluid monitoring system (300) used for fast evaluations and predictions of the properties of a drilling fluid or a fracturing fluid (204) onsite of an oilfield operation, by measuring the fluid properties under two shear rates at current temperature, predicting the fluid properties under other shear rates and under an elevated standard testing temperature, and comparing and updating results of the test to the predicted results to optimize next-time predicting practice.

Instrumentation embraces an at least partially automated rotational tapered bearing simulator viscometer having electronic control and/or monitoring that includes task unit electronics, which includes a task unit electronics interface. With or without such electronics, the instrumentation may include a particular component configuration and/or employ at least one particular material. Further feature(s) may be extant.

A fluid monitoring and management device that includes a housing with a fluid passageway. The fluid monitoring and management device further includes a fluid property sensor with a sensing element in the fluid passageway. A valve is in the fluid passageway of the fluid monitoring and management device. A removable bottle mount is aligned with the valve to be selectively in fluid communication with the fluid passageway.

A fluid monitoring and management device that includes a housing with a fluid passageway. The fluid monitoring and management device further includes a fluid property sensor with a sensing element in the fluid passageway. A valve is in the fluid passageway of the fluid monitoring and management device. A removable bottle mount is aligned with the valve to be selectively in fluid communication with the fluid passageway.

Systems and methods include a method for using reservoir simulations. Permeabilities are measured from a rock sample at different pressures using single-component gas and bulk gas viscosity values. The rock sample is representative of rock used in a reservoir simulation. For each gas component of reservoir gas, porosities are determined, including determining mean free paths for a range of temperatures and pressures encompassing conditions for both reservoir simulation input and the measured permeabilities. A characteristic pore radius for the rock is determined using the measured permeabilities and the determined porosities. Viscosity adjustment factors for a predefined range of temperatures and pressures are determined using the measured permeabilities. Adjusted gas viscosities for the predefined range of temperatures and pressures and the measured permeabilities are determined using the viscosity adjustment factors. The reservoir simulator is executed using the adjusted gas viscosities.

In order to determine a rheological property of a fluid, the fluid is conveyed with a constant volume flow rate through a nozzle and the fluid strand thereby generated is deposited on a substrate. A relative movement takes place between the nozzle and the substrate at a forward feed velocity value. A contour of the liquid strand between the nozzle and the substrate is optically measured, and an extensional viscosity as a rheological property is deduced from knowledge of the volume flow rate, the forward feed velocity value and the contour of the fluid strand.

transducer apparatus comprises a transducer housing, a tube, a temperature sensor as well as a temperature sensor. The tube is arranged within a cavity of the transducer housing, in such a manner that an intermediate space is formed between a wall of the transducer housing facing the cavity inner surface and an outer surface of a wall of the tube facing the cavity. Furthermore, the tube is adapted to guide a fluid in its lumen, in such a manner that an inner surface of the wall of the tube facing the lumen is contacted by fluid guided in the lumen. Each of the temperature sensors is formed by means of a temperature detector arranged within the intermediate space as well as by means of a coupling body coupling the respective temperature detector thermally conductively with the wall of the tube and is additionally adapted to register a particular measurement location temperature, and to transduce such into a corresponding temperature measurement signal, namely an electrical measurement signal representing the particular measurement location temperature.

Provided is a method for predicting kinematic viscosity of a fraction of a crude oil to optimize selection of crude oils. The method includes receiving parameters of the crude oil, such as Vacuum Residue yield and Conradson Carbon Residue (CCR), content as an input. The method also includes determining kinematic viscosity of the fraction of the crude oil at a first predetermined temperature based on a first correlation model between the physical parameters of the crude oil and the kinematic viscosity at the first predetermined temperature. The method further includes generating the kinematic viscosity of the fraction of the crude oil at the predetermined temperature based on the first correlation model corresponding to the input. Also provided is a system for predicting kinematic viscosity at a predetermined temperature to optimize crude oil selection. Further provided is a method for estimating an amount of cutter stock for crude oil processing.

Apparatus and methods for the continuous measurement of specific gravity or density of solids in a fluid medium are disclosed. A system for continuous measurement of density of a flowing medium comprises a cartridge connected in series to an inflow pipe and an outflow pipe, a displacement sensing device adapted to monitor displacement changes of the cartridge when a medium flows through the cartridge, a base configured to provide a support for the displacement sensing device, a pressure sensor, a temperature sensor, and a processor configured to calculate density of the flowing media based on measured displacement change, temperature and pressure.

A vibratory meter and method for verification of a vibratory sensor is provided. The method includes measuring a plurality of temperatures using a temperature sensor and measuring a plurality of sensor time periods using the sensor assembly. An average temperature and an average sensor time period are determined. The average sensor time period is compensated using the average temperature, generating a compensated sensor time period. The compensated sensor time period is compared to a reference sensor time period. The results are indicated. In further embodiments, a standard deviation of the plurality of temperatures or the plurality of sensor time periods are compared to a limit and sensor stability is indicated. In further embodiments, a difference between measured density and a reference density of a fluid is compensated using the altitude and the average temperature.