A viscometer includes a viscosity sensor with a liquid flow channel for measuring a viscosity of a liquid flowing through the liquid flow channel, a manifold with an inlet and an outlet for receiving a liquid sample through the inlet of the manifold and providing the received liquid sample through the outlet of the manifold to the viscosity sensor, and a pump coupled with the manifold for causing an in-flow of the liquid sample into the manifold through the inlet of the manifold and an out-flow of the received liquid sample from the manifold through the outlet of the manifold. Also disclosed is a viscosity sensor module with two or more viscosity sensors.

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.

Systems and methods for determining rheology characteristics of a drilling fluid include a drop-in unit sized to fit within a flowline of a drilling fluid circulation system upstream of a mud shaker. The drop-in unit has an entry funnel having an end plate with an opening through the end plate. The entrance of the entry funnel has an outer diameter that is larger than a diameter of the opening through the end plate. An instrumentation tubular is an elongated member with an inner bore that is in fluid communication with the opening through the end plate. The instrumentation tubular includes a downstream sensor and an upstream sensor. The upstream and downstream sensors are operable to sense a parameter of the drilling fluid traveling through the instrumentation tubular for calculating a change of viscosity of the drilling fluid within the flowline between a first time and a second time.

A method for verifying a density and/or viscosity measuring device in a measuring station of a process installation during ongoing operation, in which a medium flows through a main channel of the process installation, comprising steps: providing a side channel, which is connected as a bypass of the main channel, wherein the side channel is fluidically connected to the main channel via two regions of the main channel with mutually differing diameters; providing a MEMS-based master or control density measuring device in the side channel such that the MEMS-based master or control density measuring device is flowed through by the medium; performing at least one verification measurement with the MEMS-based master or control density measuring device; and verifying the density and/or viscosity measuring device based on the at least one verification measurement performed by the MEMS-based master or control density measuring device.

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.

This disclosure provides a system for measuring rheological properties of a fluid including a vessel with a shape defined by the following proportionality: x∝C ×y{circumflex over ( )}((1/n)) wherein the symbol ∝ refers to proportionality, and the variables x and y are coordinates on an x-y cartesian coordinate plane, where x is length and y is height; 2≤n≤4; and C is a constant with dimensions of length, and the vessel includes a hole at or near the y-coordinate minimum; a temperature sensor and a pressure sensor wherein the temperature sensor and pressure sensor are configured to transmit temperature and pressure information to a mobile display device, tablet, or computer, the mobile display device, tablet, or computer comprising memory and a processor and a software application configured to perform processing operations including accepting two input numerical values including density and viscosity measured by the vessel and outputting industry standard dial readings of a conventional rotational rheometer.

An apparatus for measuring properties of a thermosetting polymer includes a body having a first chamber and a second chamber each filled with the thermosetting polymer material. A first FBG sensor is disposed in the polymer material within the first chamber and a second FBG sensor is disposed in the polymer material within the second chamber. A first dielectric constant sensor is in the first chamber, and a second dielectric constant sensor is in the second chamber. A computing device is configured to measure properties of the thermosetting polymer based on wavelength data measured using the first FBG sensor and the second FBG sensor, and a loss coefficient of the polymer material measured using the first dielectric constant sensor and the second dielectric constant sensor, while the thermosetting polymer solidifies in the first chamber and the second chamber.

Systems and methods for determining rheology characteristics of a drilling fluid include a drop-in unit sized to fit within a flowline of a drilling fluid circulation system upstream of a mud shaker. The drop-in unit has an entry funnel having an end plate with an opening through the end plate. The entrance of the entry funnel has an outer diameter that is larger than a diameter of the opening through the end plate. An instrumentation tubular is an elongated member with an inner bore that is in fluid communication with the opening through the end plate. The instrumentation tubular includes a downstream sensor and an upstream sensor. The upstream and downstream sensors are operable to sense a parameter of the drilling fluid traveling through the instrumentation tubular for calculating a change of viscosity of the drilling fluid within the flowline between a first time and a second time.

This disclosure provides a system for measuring rheological properties of a fluid including a vessel with a shape defined by the following proportionality: x∝C ×y {circumflex over ( )}((1/n)) wherein the symbol ∝ refers to proportionality, and the variables x and y are coordinates on an x-y cartesian coordinate plane, where x is length and y is height; 2≤n≤4; and C is a constant with dimensions of length, and the vessel includes a hole at or near the y-coordinate minimum; a temperature sensor and a pressure sensor wherein the temperature sensor and pressure sensor are configured to transmit temperature and pressure information to a mobile display device, tablet, or computer, the mobile display device, tablet, or computer comprising memory and a processor and a software application configured to perform processing operations including accepting two input numerical values including density and viscosity measured by the vessel and outputting industry standard dial readings of a conventional rotational rheometer.

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.